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MAJOR SOURCE OPERATING PERMIT
PERMITTEE: Hunt Refining Company
FACILITY NAME: Tuscaloosa Petroleum Refinery
FACILITY/PERMIT NO.: 413-0007
LOCATION: 1855 Fairlawn Dr., Tuscaloosa, Tuscaloosa County,
Alabama
In accordance with and subject to the provisions of the Alabama Air Pollution Control Act of 1971, as
amended, Ala. Code 1975, §§22-28-1 to 22-28-23 (2006 Rplc. Vol. and 2007 Cum. Supp.) (the "AAPCA")
and the Alabama Environmental Management Act, as amended, Ala. Code 1975, §§22-22A-1 to
22-22A-15, (2006 Rplc. Vol. and 2007 Cum. Supp.) and rules and regulations adopted thereunder, and
subject further to the conditions set forth in this permit, the Permittee is hereby authorized to construct,
install and use the equipment, device or other article described above.
Pursuant to the Clean Air Act of 1990, all conditions of this permit are federally enforceable by EPA, the Alabama Department of Environmental Management, and citizens in general. Those provisions which are not required under the Clean Air Act of 1990 are considered to be state permit provisions and are not federally enforceable by EPA and citizens in general. Those provisions are contained in separate sections of this permit.
Issuance Date: DRAFT June 24, 2020
Effective Date:
Expiration Date:
Alabama Department of Environmental Management
[THIS PAGE LEFT BLANK INTENTIIONALLY]
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TABLE OF CONTENTS
GENERAL PERMIT PROVISOS .............................................................................................................. 1
SUMMARY PAGE FOR PRE-BLACK WARRIOR EXPANSION UNITS: PROCESS HEATERS & BOILERS ......... 17
PROVISOS FOR PRE-BLACK WARRIOR EXPANSION UNITS: PROCESS HEATERS & BOILERS ................... 21
Applicability ........................................................................................................................................ 21
Emission Standards ............................................................................................................................ 22
Compliance and Performance Test Methods and Procedures .......................................................... 26
Emission Monitoring .......................................................................................................................... 27
Recordkeeping and Reporting Requirements .................................................................................... 30
SUMMARY PAGE FOR POST-BLACK WARRIOR EXPANSION UNITS: PROCESS HEATERS & BOILERS ....... 37
PROVISOS FOR POST-BLACK WARRIOR EXPANSION UNITS: PROCESS HEATERS & BOILERS ................. 39
Applicability ........................................................................................................................................ 39
Emission Standards ............................................................................................................................ 40
Compliance and Performance Test Methods and Procedures .......................................................... 42
Emission Monitoring .......................................................................................................................... 45
Recordkeeping and Reporting Requirements .................................................................................... 47
SUMMARY PAGE FOR EMERGENCY ENGINES .................................................................................... 53
PROVISOS FOR EMERGENCY ENGINES............................................................................................... 58
Applicability ........................................................................................................................................ 58
Emission Standards ............................................................................................................................ 59
Compliance and Performance Test Methods and Procedures .......................................................... 63
Emission Monitoring .......................................................................................................................... 64
Recordkeeping and Reporting Requirements .................................................................................... 65
SUMMARY PAGE FOR NSPS QQQ: OILY WASTEWATER SYSTEM ......................................................... 69
PROVISOS FOR OILY WASTEWATER SYSTEM ..................................................................................... 70
Applicability ........................................................................................................................................ 70
Emission Standards ............................................................................................................................ 70
Compliance and Performance Test Methods and Procedures .......................................................... 71
Emission Monitoring .......................................................................................................................... 71
Recordkeeping and Reporting Requirements .................................................................................... 72
SUMMARY PAGE FOR MACT CC AND BWON NESHAP: WASTEWATER STREAM CONTAINING HAPS .... 75
PROVISOS FOR WASTEWATER STREAM CONTAINING HAPS .............................................................. 76
Applicability ........................................................................................................................................ 76
Emission Standards ............................................................................................................................ 77
Compliance and Performance Test Methods and Procedures .......................................................... 78
Emission Monitoring .......................................................................................................................... 78
ii
Recordkeeping and Reporting Requirements .................................................................................... 78
SUMMARY PAGE FOR NSPS VVA & MON: DI-METHYL SULFIDE (DMS) UNIT ....................................... 81
PROVISOS FOR DMS UNIT ................................................................................................................ 82
Applicability ........................................................................................................................................ 82
Emission Standards ............................................................................................................................ 82
Compliance and Performance Test Methods and Procedures .......................................................... 85
Emission Monitoring .......................................................................................................................... 85
Recordkeeping and Reporting Requirements .................................................................................... 86
SUMMARY PAGE FOR NSPS K: PETROLEUM LIQUID STORAGE VESSELS .............................................. 89
PROVISOS FOR NSPS K PETROLEUM LIQUID STORAGE VESSELS ......................................................... 90
Applicability ........................................................................................................................................ 90
Emission Standards ............................................................................................................................ 90
Compliance and Performance Test Methods and Procedures .......................................................... 91
Emission Monitoring .......................................................................................................................... 91
Recordkeeping and Reporting Requirements .................................................................................... 91
SUMMARY PAGE FOR NSPS KA: PETROLEUM LIQUID STORAGE VESSELS ........................................... 95
PROVISOS FOR NSPS KA PETROLEUM LIQUID STORAGE VESSELS ....................................................... 96
Applicability ........................................................................................................................................ 96
Emission Standards ............................................................................................................................ 96
Compliance and Performance Test Methods and Procedures .......................................................... 97
Emission Monitoring .......................................................................................................................... 98
Recordkeeping and Reporting Requirements .................................................................................... 98
SUMMARY PAGE FOR NSPS KB PETROLEUM LIQUID STORAGE VESSELS ........................................... 101
PROVISOS FOR NSPS KB PETROLEUM LIQUID STORAGE VESSELS ..................................................... 102
Emission Standards .......................................................................................................................... 102
Compliance and Performance Test Methods and Procedures ........................................................ 103
Emission Monitoring ........................................................................................................................ 104
Recordkeeping and Reporting Requirements .................................................................................. 105
SUMMARY PAGE FOR MACT CC: ORGANIC HAP STORAGE VESSELS .................................................. 109
PROVISOS FOR MACT CC: ORGANIC HAP STORAGE VESSELS ............................................................ 111
Applicability ...................................................................................................................................... 111
Emission Standards .......................................................................................................................... 113
Emission Monitoring ........................................................................................................................ 115
Compliance and Performance Test Methods and Procedures ........................................................ 117
Recordkeeping and Reporting Requirements .................................................................................. 117
iii
SUMMARY PAGE FOR MACT EEEE: (NON-GASOLINE) ORGANIC LIQUIDS DISTRIBUTION (OLD) SYSTEMS
HANDLING HAPS ............................................................................................................................ 121
PROVISOS FOR NON-GASOLINE OLD SYSTEMS HANDLING HAPS ...................................................... 122
Applicability ...................................................................................................................................... 122
Emission Standards .......................................................................................................................... 123
Emission Monitoring ........................................................................................................................ 125
Compliance and Performance Test Methods and Procedures ........................................................ 128
Recordkeeping and Reporting Requirements .................................................................................. 128
SUMMARY PAGE FOR NSPS GGG: FUGITIVE EQUIPMENT LEAKS ...................................................... 133
PROVISOS FOR SUMMARY PAGE FOR FUGITIVE EQUIPMENT LEAKS ................................................ 134
Emission Standards .......................................................................................................................... 135
Compliance and Performance Test Methods and Procedures ........................................................ 136
Emission Monitoring ........................................................................................................................ 136
Recordkeeping and Reporting Requirement .................................................................................... 136
SUMMARY PAGE FOR NSPS GGGA: FUGITIVE EQUIPMENT LEAKS OF VOC & OHAP EMISSIONS ......... 139
PROVISOS FOR FUGITIVE EQUIPMENT LEAKS OF VOC & OHAP EMISSIONS ....................................... 140
Emission Standards .......................................................................................................................... 141
Compliance and Performance Test Methods and Procedures ........................................................ 142
Emission Monitoring ........................................................................................................................ 142
Recordkeeping and Reporting Requirement .................................................................................... 142
SUMMARY PAGE FOR MACT CC: GASOLINE LOADING RACK AND VAPOR COMBUSTOR .................... 145
PROVISOS FOR SUMMARY PAGE FOR GASOLINE LOADING RACK AND VAPOR COMBUSTOR ............ 146
Applicability ...................................................................................................................................... 146
Emission Standards .......................................................................................................................... 147
Compliance and Performance Test Methods and Procedures ........................................................ 149
Emission Monitoring ........................................................................................................................ 150
Recordkeeping and Reporting Requirements .................................................................................. 153
SUMMARY PAGE FOR NESHAP Y AND MACT CC: MARINE VESSEL LOADING OPERATIONS ................ 157
PROVISOS FOR SUMMARY PAGE FOR MARINE VESSEL LOADING OPERATIONS ................................ 158
Applicability ...................................................................................................................................... 158
Emission Standards .......................................................................................................................... 158
Compliance and Performance Test Methods and Procedures ........................................................ 159
Emission Monitoring ........................................................................................................................ 160
Recordkeeping and Reporting Requirements .................................................................................. 160
SUMMARY PAGE FOR MACT CC: HEAT EXCHANGERS (COOLING TOWERS) ....................................... 161
PROVISOS FOR HAPS FROM COOLING TOWERS............................................................................... 162
iv
Applicability ...................................................................................................................................... 162
Emission Standards .......................................................................................................................... 162
Compliance and Performance Test Methods and Procedures ........................................................ 163
Emission Monitoring ........................................................................................................................ 163
Recordkeeping and Reporting Requirements .................................................................................. 164
SUMMARY PAGE FOR MACT CC: FENCELINE MONITORING FOR BENZENE EMISSIONS ...................... 167
PROVISOS FOR MACT CC: FENCELINE MONITORING FOR BENZENE EMISSIONS ................................ 168
Applicability ...................................................................................................................................... 168
Emission Standards .......................................................................................................................... 168
Compliance and Performance Test Methods and Procedures ........................................................ 168
Emission Monitoring ........................................................................................................................ 169
Recordkeeping and Reporting Requirements .................................................................................. 169
SUMMARY PAGE FOR NSPS JA AND MACT CC: DELAYED COKING UNITS (DCU) PROCESS VENTS ....... 171
PROVISOS FOR DCU PROCESS VENTS .............................................................................................. 172
Applicability ...................................................................................................................................... 172
Emission Standards .......................................................................................................................... 172
Compliance and Performance Test Methods and Procedures ........................................................ 173
Emission Monitoring ........................................................................................................................ 173
Recordkeeping and Reporting Requirements .................................................................................. 174
SUMMARY PAGE FOR MACT CC: MISCELLANEOUS PROCESS VENTS (INCLUDING MAINTENANCE VENTS
AND BYPASS LINES) ........................................................................................................................ 177
SUMMARY PAGE FOR MISCELLANEOUS PROCESS VENTS (INCLUDING MAINTENANCE VENTS) .......... 178
Applicability ...................................................................................................................................... 178
Emission Standards .......................................................................................................................... 178
Compliance and Performance Test Methods and Procedures ........................................................ 180
Emission Monitoring ........................................................................................................................ 181
Recordkeeping and Reporting Requirements .................................................................................. 182
SUMMARY PAGE FOR MACT UUU: BYPASS LINES FOR CRU AND SRU VENTS .................................... 185
PROVISOS FOR BYPASS LINES FOR CRU AND SRU VENTS ................................................................. 186
Applicability ...................................................................................................................................... 186
Emission Standards .......................................................................................................................... 186
Compliance and Performance Test Methods and Procedures ........................................................ 187
Emission Monitoring ........................................................................................................................ 187
Recordkeeping and Reporting Requirements .................................................................................. 188
SUMMARY PAGE FOR MACT UUU: CATALYTIC REFORMING UNIT (CRU) VENTS ................................ 191
PROVISOS FOR CATALYTIC REFORMING UNIT (CRU) VENTS ............................................................. 192
v
Applicability ...................................................................................................................................... 192
Emission Standards .......................................................................................................................... 192
Compliance and Performance Test Methods and Procedures ........................................................ 194
Emission Monitoring ........................................................................................................................ 194
Recordkeeping and Reporting Requirements .................................................................................. 196
SUMMARY PAGE FOR NSPS J AND MACT UUU: SULFUR RECOVERY SYSTEMS & THERMAL
OXIDIZERS ..................................................................................................................................... 199
PROVISOS FOR SULFUR RECOVERY SYSTEMS & THERMAL OXIDIZERS .............................................. 200
Applicability ...................................................................................................................................... 200
Emission Standards .......................................................................................................................... 201
Compliance and Performance Test Methods and Procedures ........................................................ 203
Emission Monitoring ........................................................................................................................ 205
Recordkeeping and Reporting Requirements .................................................................................. 207
SUMMARY PAGE FOR NSPS JA & MACT CC: PROCESS FLARES AND ASSOCIATED PROCESS UNIT
VENTS ............................................................................................................................................ 211
PROVISOS FOR PROCESS FLARES AND ASSOCIATED PROCESS UNIT VENTS ....................................... 213
Applicability ...................................................................................................................................... 213
Emission Standards .......................................................................................................................... 214
Compliance and Performance Test Methods and Procedures ........................................................ 216
Emission Monitoring ........................................................................................................................ 219
Recordkeeping and Reporting Requirements .................................................................................. 223
SUMMARY PAGE FOR MACT LLLLL: ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER .............. 227
PROVISOS FOR ASPHALT PROCESSING FACILITIES & THERMAL OXIDIZER ......................................... 228
Applicability ...................................................................................................................................... 228
Emission Standards .......................................................................................................................... 229
Compliance and Performance Test Methods and Procedures ........................................................ 232
Emission Monitoring ........................................................................................................................ 233
Recordkeeping and Reporting Requirements .................................................................................. 235
SUMMARY PAGE FOR PETROLEUM COKE DRYING AND PULVERIZING SYSTEMS ............................... 245
PROVISOS FOR PETROLEUM COKE DRYING AND PULVERIZING SYSTEMS ......................................... 246
Applicability ...................................................................................................................................... 246
Emission Standards .......................................................................................................................... 246
Compliance and Performance Test Methods and Procedures ........................................................ 247
Emission Monitoring ........................................................................................................................ 248
Recordkeeping and Reporting Requirements .................................................................................. 248
APPENDIX A: HEATERS & BOILERS MONITORING ............................................................................ 251
APPENDIX B: GASOLINE LOADING RACK AND VAPOR COMBUSTOR UNIT ......................................... 259
vi
APPENDIX C: SULFUR RECOVERY SYSTEMS’ THERMAL OXIDIZER ...................................................... 263
APPENDIX D: FACILITY FLARE MONITORING .................................................................................... 265
APPENDIX E: ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER MONITORING ......................... 267
APPENDIX F: PETROLEUM COKE DRYING & PULVERIZING SYSTEM ................................................... 271
1
General Permit Provisos
Federally Enforceable Provisos Regulations
1. Transfer
This permit is not transferable, whether by operation of law or otherwise, either
from one location to another, from one piece of equipment to another, or from
one person to another, except as provided in Rule 335-3-16-.13(1)(a)5.
Rule 335-3-16-.02(6)
2. Renewals
An application for permit renewal shall be submitted at least six (6) months, but
not more than eighteen (18) months, before the date of expiration of this
permit.
The source for which this permit is issued shall lose its right to operate upon the
expiration of this permit unless a timely and complete renewal application has
been submitted within the time constraints listed in the previous paragraph.
Rule 335-3-16-.12(2)
3. Severability Clause
The provisions of this permit are declared to be severable and if any section,
paragraph, subparagraph, subdivision, clause, or phrase of this permit shall be
adjudged to be invalid or unconstitutional by any court of competent
jurisdiction, the judgment shall not affect, impair, or invalidate the remainder
of this permit, but shall be confined in its operation to the section, paragraph,
subparagraph, subdivision, clause, or phrase of this permit that shall be directly
involved in the controversy in which such judgment shall have been rendered.
Rule 335-3-16-.05(e)
4. Compliance
(a) The permittee shall comply with all conditions of ADEM Admin. Code
335-3. Noncompliance with this permit will constitute a violation of the
Clean Air Act of 1990 and ADEM Admin. Code 335-3 and may result in
an enforcement action; including but not limited to, permit termination,
revocation and reissuance, or modification; or denial of a permit
renewal application by the permittee.
Rule 335-3-16-.05(f)
(b) The permittee shall not use as a defense in an enforcement action that
maintaining compliance with conditions of this permit would have
required halting or reducing the permitted activity.
Rule 335-3-16-.05(g)
5. Termination for Cause
This permit may be modified, revoked, reopened and reissued, or terminated
for cause. The filing of a request by the permittee for a permit modification,
revocation and reissuance, or termination, or of a notification of planned
changes or anticipated noncompliance will not stay any permit condition.
Rule 335-3-16-.05(h)
2
General Permit Provisos
Federally Enforceable Provisos Regulations
6. Property Rights
The issuance of this permit does not convey any property rights of any sort, or
any exclusive privilege.
Rule 335-3-16-.05(i)
7. Submission of Information
The permittee must submit to the Department, within 30 days or for such other
reasonable time as the Department may set, any information that the
Department may request in writing to determine whether cause exists for
modifying, revoking and reissuing, or terminating this permit or to determine
compliance with this permit. Upon receiving a specific request, the permittee
shall also furnish to the Department copies of records required to be kept by
this permit.
Rule 335-3-16-.05(j)
8. Economic Incentives, Marketable Permits, and Emissions Trading
No permit revision shall be required, under any approved economic incentives,
marketable permits, emissions trading and other similar programs or processes
for changes that are provided for in this permit.
Rule 335-3-16-.05(k)
9. Certification of Truth, Accuracy, and Completeness:
Any application form, report, test data, monitoring data, or compliance
certification submitted pursuant to this permit shall contain certification by a
responsible official of truth, accuracy, and completeness. This certification shall
state that, based on information and belief formed after reasonable inquiry, the
statements and information in the document are true, accurate and complete.
Rule 335-3-16-.07(a)
10. Inspection and Entry
Upon presentation of credentials and other documents as may be required by
law, the permittee shall allow authorized representatives of the Alabama
Department of Environmental Management and EPA to conduct the following:
Rule 335-3-16-.07(b)
(a) Enter upon the permittee’s premises where a source is located or
emissions-related activity is conducted, or where records must be kept
pursuant to the conditions of this permit;
(b) Review and/or copy, at reasonable times, any records that must be kept
pursuant to the conditions of this permit;
(c) Inspect, at reasonable times, this facility’s equipment (including
monitoring equipment and air pollution control equipment), practices,
or operations regulated or required pursuant to this permit;
3
General Permit Provisos
Federally Enforceable Provisos Regulations
(d) Sample or monitor, at reasonable times, substances or parameters for
the purpose of assuring compliance with this permit or other applicable
requirements.
11. Compliance Provisions
(a) The permittee shall continue to comply with the applicable
requirements with which the company has certified that it is already in
compliance.
Rule 335-3-16-.07(c)
(b) The permittee shall comply in a timely manner with applicable
requirements that become effective during the term of this permit.
12. Compliance Certification
On, or before, March 1, a compliance certification shall be submitted. Rule 335-3-16-.07(e)
(a) The compliance certification shall include the following:
(1) The identification of each term or condition of this permit that
is the basis of the certification;
(2) The compliance status;
(3) The method(s) used for determining the compliance status of
the source, currently and over the reporting period consistent
with Rule 335-3-16-.05(c) (Monitoring and Recordkeeping
Requirements);
(4) Whether compliance has been continuous or intermittent;
(5) Such other facts as the Department may require to determine
the compliance status of the source;
(b) The compliance certification shall be submitted to:
Alabama Department of Environmental Management
Air Division
P.O. Box 301463
Montgomery, AL 36130-1463
and to:
Director, Air Enforcement and Toxics Branch
EPA Region 4
61 Forsyth Street, SW
Atlanta, GA 30303
4
General Permit Provisos
Federally Enforceable Provisos Regulations
13. Reopening for Cause
Under any of the following circumstances, this permit will be reopened prior to
the expiration of the permit:
Rule 335-3-16-.13(5)
(a) Additional applicable requirements under the Clean Air Act of 1990
become applicable to the permittee with a remaining permit term of
three (3) or more years. Such a reopening shall be completed not later
than eighteen (18) months after promulgation of the applicable
requirement. No such reopening is required if the effective date of the
requirement is later than the date on which this permit is due to expire.
(b) Additional requirements (including excess emissions requirements)
become applicable to an affected source under the acid rain program.
Upon approval by the Administrator, excess emissions offset plans shall
be deemed to be incorporated into this permit.
(c) The Department or EPA determines that this permit contains a material
mistake or that inaccurate statements were made in establishing the
emissions standards or other terms or conditions of this permit.
(d) The Administrator or the Department determines that this permit must
be revised or revoked to assure compliance with the applicable
requirements.
14. Additional Rules and Regulations
This permit is issued on the basis of Rules and Regulations existing on the date
of issuance. In the event additional Rules and Regulations are adopted, it shall
be the permit holder’s responsibility to comply with such rules.
§22-28-16(d), Code of
Alabama 1975, as
amended
15. Equipment Maintenance or Breakdown
(a) In the case of shutdown of air pollution control equipment (which
operates pursuant to any permit issued by the Director) for necessary
scheduled maintenance, the intent to shut down such equipment shall
be reported to the Director at least twenty-four (24) hours prior to the
planned shutdown, unless such shutdown is accompanied by the
shutdown of the source which such equipment is intended to control.
Such prior notice shall include, but is not limited to the following:
Rule 335-3-1-.07(1), (2)
(1) Identification of the specific facility to be taken out of service as
well as its location and permit number;
5
General Permit Provisos
Federally Enforceable Provisos Regulations
(2) The expected length of time that the air pollution control
equipment will be out of service;
(3) The nature and quantity of emissions of air contaminants likely
to occur during the shutdown period;
(4) Measures such as the use of off-shift labor and equipment that
will be taken to minimize the length of the shutdown period;
(5) The reasons that it would be impossible or impractical to shut
down the source operation during the maintenance period.
(b) In the event that there is a breakdown of equipment or upset of process
in such a manner as to cause, or is expected to cause, increased
emissions of air contaminants which are above an applicable standard,
the person responsible for such equipment shall notify the Director
within 24 hours or the next working day and provide a statement giving
all pertinent facts, including the estimated duration of the breakdown.
The Director shall be notified when the breakdown has been corrected.
16. Operation of Capture and Control Devices
All air pollution control devices and capture systems for which this permit is
issued shall be maintained and operated at all times in a manner so as to
minimize the emissions of air contaminants. Procedures for ensuring that the
above equipment is properly operated and maintained so as to minimize the
emission of air contaminants shall be established.
§22-28-16(d), Code of
Alabama 1975, as
amended
17. Obnoxious Odors
This permit is issued with the condition that, should obnoxious odors arising
from the plant operations be verified by Air Division inspectors, measures to
abate the odorous emissions shall be taken upon a determination by the
Alabama Department of Environmental Management that these measures are
technically and economically feasible.
Rule 335-3-1-.08
18. Fugitive Dust
(a) Precautions shall be taken to prevent fugitive dust emanating from
plant roads, grounds, stockpiles, screens, dryers, hoppers, ductwork,
etc.
Rule 335-3-4-.02
(b) Plant or haul roads and grounds will be maintained in the following
manner so that dust will not become airborne. A minimum of one, or a
combination, of the following methods shall be utilized to minimize
airborne dust from plant or haul roads and grounds:
6
General Permit Provisos
Federally Enforceable Provisos Regulations
(1) By the application of water any time the surface of the road is
sufficiently dry to allow the creation of dust emissions by the
act of wind or vehicular traffic;
(2) By reducing the speed of vehicular traffic to a point below that
at which dust emissions are created;
(3) By paving;
(4) By the application of binders to the road surface at any time the
road surface is found to allow the creation of dust emissions;
Should one, or a combination, of the above methods fail to adequately reduce
airborne dust from plant or haul roads and grounds, alternative methods shall
be employed, either exclusively or in combination with one or all of the above
control techniques, so that dust will not become airborne. Alternative methods
shall be approved by the Department prior to utilization.
19. Additions and Revisions
Any modifications to this source shall comply with the modification procedures
in Rules 335-3-16-.13 or 335-3-16-.14.
Rule 335-3-16-.13 and .14
20. Recordkeeping Requirements
(a) Records of required monitoring information of the source shall include
the following:
Rule 335-3-16-.05(c)(2).
(1) The date, place, and time of all sampling or measurements;
(2) The date analyses were performed;
(3) The company or entity that performed the analyses;
(4) The analytical techniques or methods used;
(5) The results of all analyses; and
(6) The operating conditions that existed at the time of sampling or
measurement.
(b) Retention of records of all required monitoring data and support
information of the source is required for a period of at least 5 years from
the date of the monitoring sample, measurement, report, or
application. Support information includes all calibration and
maintenance records and all original strip-chart recordings for
7
General Permit Provisos
Federally Enforceable Provisos Regulations
continuous monitoring instrumentation and copies of all reports
required by the permit
21. Reporting Requirements
(a) Reports to the Department of any required monitoring shall be
submitted at least every 6 months. All instances of deviations from
permit requirements must be clearly identified in said reports. All
required reports must be certified by a responsible official consistent
with Rule 335-3-16-.04(9).
Rule 335-3-16-.05(c)(3).
(b) Deviations from permit requirements shall be reported within 48 hours
or 2 working days of such deviations, including those attributable to
upset conditions as defined in the permit. The report will include the
probable cause of said deviations, and any corrective actions or
preventive measures that were taken.
22. Emission Testing Requirements
Each point of emission which requires testing will be provided with sampling
ports, ladders, platforms, and other safety equipment to facilitate testing
performed in accordance with procedures established by Part 60, of Title 40 of
the Code of Federal Regulations, as the same may be amended or revised.
Rule 335-3-1-.05(3) and
Rule 335-3-1-.04(1)
The Air Division must be notified in writing at least 10 days in advance of all
emission tests to be conducted and submitted as proof of compliance with the
Department’s air pollution control rules and regulations.
To avoid problems concerning testing methods and procedures, the following
shall be included with the notification letter:
(1) The date the test crew is expected to arrive, the date and time
anticipated of the start of the first run, how many and which sources are
to be tested, and the names of the persons and/or testing company that
will conduct the tests.
Rule 335-3-1-.04
(2) A complete description of each sampling train to be used, including type
of media used in determining gas stream components, type of probe
lining, type of filter media, and probe cleaning method and solvent to
be used (if test procedures require probe cleaning).
(3) A description of the process(es) to be tested including the feed rate, any
operating parameters used to control or influence the operations, and
the rated capacity.
8
General Permit Provisos
Federally Enforceable Provisos Regulations
(4) A sketch or sketches showing sampling point locations and their relative
positions to the nearest upstream and downstream gas flow
disturbances.
A pretest meeting may be held at the request of the source owner or the Air
Division. The necessity for such a meeting and the required attendees will be
determined on a case-by-case basis.
All test reports must be submitted to the Air Division within 30 days of the actual
completion of the test unless an extension of time is specifically approved by
the Air Division.
Rule 335-3-1-.04
23. Payment of Emission Fees
Annual emission fees shall be remitted each year according to the fee schedule
in ADEM Admin. Code r. 335-1-7-.04.
Rule 335-1-7-.04
24. Other Reporting and Testing Requirements
Submission of other reports regarding monitoring records, fuel analyses,
operating rates, and equipment malfunctions may be required as authorized in
the Department's air pollution control rules and regulations. The Department
may require emission testing at any time.
Rule 335-3-1-.04(1)
25. Title VI Requirements (Refrigerants)
Any facility having appliances or refrigeration equipment, including air
conditioning equipment, which use Class I or Class II ozone-depleting substances
as listed in 40 CFR Part 82, Subpart A, Appendices A and B, shall service, repair,
and maintain such equipment according to the work practices, personnel
certification requirements, and certified recycling and recovery equipment
specified in 40 CFR Part 82, Subpart F.
No person shall knowingly vent or otherwise release any Class I or Class II
substance into the environment during the repair, servicing, maintenance, or
disposal of any device except as provided in 40 CFR Part 82, Subpart F.
The responsible official shall comply with all reporting and recordkeeping
requirements of 40 CFR §82.166. Reports shall be submitted to the US EPA and
the Department as required.
40 CFR Part 82
26. Chemical Accidental Prevention Provisions
If a chemical listed in Table 1 of 40 CFR §68.130 is present in a process in
quantities greater than the threshold quantity listed in Table 1, then:
40 CFR Part 68
9
General Permit Provisos
Federally Enforceable Provisos Regulations
(a) The owner or operator shall comply with the provisions in 40 CFR Part
68.
(b) The owner or operator shall submit one of the following:
(1) A compliance schedule for meeting the requirements of 40 CFR
Part 68 by the date provided in 40 CFR §68.10(a) or,
(2) A certification statement that the source is in compliance with
all requirements of 40 CFR Part 68, including the registration
and submission of the Risk Management Plan.
27. Display of Permit
This permit shall be kept under file or on display at all times at the site where
the facility for which the permit is issued is located and will be made readily
available for inspection by any or all persons who may request to see it.
Rule 335-3-14-.01(1)(d)
28. Circumvention
No person shall cause or permit the installation or use of any device or any
means which, without resulting in reduction in the total amount of air
contaminant emitted, conceals or dilutes any emission of air contaminant which
would otherwise violate the Division 3 rules and regulations.
Rule 335-3-1-.10
29. Visible Emissions
Unless otherwise specified in the Unit Specific provisos of this permit, any
source of particulate emissions shall not discharge more than one 6-minute
average opacity greater than 20% in any 60-minute period. At no time shall any
source discharge a 6-minute average opacity of particulate emissions greater
than 40%. Opacity will be determined by 40 CFR Part 60, Appendix A, Method
9, unless otherwise specified in the Unit Specific provisos of this permit.
Rule 335-3-4-.01(1)
30. Fuel-Burning Equipment
(a) Unless otherwise specified in the Unit Specific provisos of this permit,
no fuel-burning equipment may discharge particulate emissions in
excess of the emissions specified in Part 335-3-4-.03.
(b) Unless otherwise specified in the Unit Specific provisos of this permit,
no fuel-burning equipment may discharge sulfur dioxide emissions in
excess of the emissions specified in Part 335-3-5-.01.
Rule 335-3-4-.03
Rule 335-3-5-.01
10
General Permit Provisos
Federally Enforceable Provisos Regulations
31. Process Industries – General
Unless otherwise specified in the Unit Specific provisos of this permit, no
process may discharge particulate emissions in excess of the emissions specified
in Part 335-3-4-.04.
Rule 335-3-4-.04
32. Averaging Time for Emission Limits
Unless otherwise specified in the permit, the averaging time for the emission
limits listed in this permit shall be the nominal time required by the specific test
method.
Rule 335-3-1-.05
33. Compliance Assurance Monitoring (CAM)
Conditions (a) through (d) that follow are general conditions applicable to
emissions units that are subject to the CAM requirements. Specific
requirements related to each emissions unit are contained in the unit specific
provisos and the attached CAM appendices.
(a) Operation of Approved Monitoring 40 CFR 64.7
(1) Commencement of operation. The owner or operator shall
conduct the monitoring required under this section and
detailed in the unit specific provisos and CAM appendix of this
permit (if required) upon issuance of the permit, or by such later
date specified in the permit pursuant to §64.6(d).
(2) Proper maintenance. At all times, the owner or operator shall
maintain the monitoring, including but not limited to,
maintaining necessary parts for routine repairs of the
monitoring equipment.
(3) Continued operation. Except for, as applicable, monitoring
malfunctions, associated repairs, and required quality
assurance or control activities (including, as applicable,
calibration checks and required zero and span adjustments), the
owner or operator shall conduct all monitoring in continuous
operation (or shall collect data at all required intervals) at all
times that the pollutant-specific emissions unit is operating.
Data recorded during monitoring malfunctions, associated
repairs, and required quality assurance or control activities shall
not be used for purposes of this part, including data averages
and calculations, or fulfilling a minimum data availability
requirement, if applicable. The owner or operator shall use all
the data collected during all other periods in assessing the
operation of the control device and associated control system.
A monitoring malfunction is any sudden, infrequent, not
11
General Permit Provisos
Federally Enforceable Provisos Regulations
reasonably preventable failure of the monitoring to provide
valid data. Monitoring failures that are caused in part by poor
maintenance or careless operation are not malfunctions.
(4) Response to excursions or exceedances. (a) Upon detecting an
excursion or exceedance, the owner or operator shall restore
operation of the pollutant-specific emissions unit (including the
control device and associated capture system) to its normal or
usual manner of operation as expeditiously as practicable in
accordance with good air pollution control practices for
minimizing emissions. The response shall include minimizing the
period of any startup, shutdown or malfunction and taking any
necessary corrective actions to restore normal operation and
prevent the likely recurrence of the cause of an excursion or
exceedance (other than those caused by excused startup or
shutdown conditions). Such actions may include initial
inspection and evaluation, recording that operations returned
to normal without operator action (such as through response by
a computerized distribution control system), or any necessary
follow-up actions to return operation to within the indicator
range, designated condition, or below the applicable emission
limitation or standard, as applicable. (b) Determination of
whether the owner or operator has used acceptable
procedures in response to an excursion or exceedance will be
based on information available, which may include but is not
limited to, monitoring results, review of operation and
maintenance procedures and records, and inspection of the
control device, associated capture system, and the process.
(5) Documentation of need for improved monitoring. After
approval of monitoring under this part, if the owner or operator
identifies a failure to achieve compliance with an emission
limitation or standard for which the approved monitoring did
not provide an indication of an excursion or exceedance while
providing valid data, or the results of compliance or
performance testing document a need to modify the existing
indicator ranges or designated conditions, the owner or
operator shall promptly notify the Department and, if
necessary, submit a proposed modification to the permit to
address the necessary monitoring changes. Such a modification
may include, but is not limited to, reestablishing indicator
ranges or designated conditions, modifying the frequency of
conducting monitoring and collecting data, or the monitoring of
additional parameters.
(b) Quality Improvement Plan (QIP) Requirements 40 CFR 64.8
12
General Permit Provisos
Federally Enforceable Provisos Regulations
(1) Based on the results of a determination made under Section
33(a)(4)(b) above, the Administrator or the permitting authority
may require the owner or operator to develop and implement
a QIP. Consistent with 40 CFR §64.6(c)(3), the permit may
specify an appropriate threshold, such as an accumulation of
exceedances or excursions exceeding 5 percent duration of a
pollutant-specific emissions unit's operating time for a
reporting period, for requiring the implementation of a QIP. The
threshold may be set at a higher or lower percent or may rely
on other criteria for purposes of indicating whether a pollutant-
specific emissions unit is being maintained and operated in a
manner consistent with good air pollution control practices.
(2) Elements of a QIP:
A. The owner or operator shall maintain a written QIP, if
required, and have it available for inspection.
B. The plan initially shall include procedures for evaluating
the control performance problems and, based on the
results of the evaluation procedures, the owner or
operator shall modify the plan to include procedures for
conducting one or more of the following actions, as
appropriate:
(i) Improved preventive maintenance practices.
(ii) Process operation changes.
(iii) Appropriate improvements to control
methods.
(iv) Other steps appropriate to correct control
performance.
(v) More frequent or improved monitoring (only in
conjunction with one or more steps under
paragraphs (2)(b)(i) through (iv) above).
(3) If a QIP is required, the owner or operator shall develop and
implement a QIP as expeditiously as practicable and shall notify
the Department if the period for completing the improvements
contained in the QIP exceeds 180 days from the date on which
the need to implement the QIP was determined.
(4) Following implementation of a QIP, upon any subsequent
determination pursuant to Section 33(a)(4)(b) above, the
13
General Permit Provisos
Federally Enforceable Provisos Regulations
Department may require that an owner or operator make
reasonable changes to the QIP if the QIP is found to have:
A. Failed to address the cause of the control device
performance problems; or
B. Failed to provide adequate procedures for correcting
control device performance problems as expeditiously
as practicable in accordance with good air pollution
control practices for minimizing emissions.
(5) Implementation of a QIP shall not excuse the owner or
operator of a source from compliance with any existing
emission limitation or standard, or any existing monitoring,
testing, reporting or recordkeeping requirement that may
apply under federal, state, or local law, or any other applicable
requirements under the Act.
(c) Reporting and Recordkeeping Requirements 40 CFR 64.9
(1) General reporting requirements
A. On and after the date specified in Section 33(a)(1)
above by which the owner or operator must use
monitoring that meets the requirements of this part,
the owner or operator shall submit monitoring reports
to the permitting authority in accordance with ADEM
Admin. Code r. 335-3-16-.05(c)(3.)
B. A report for monitoring under this part shall include, at
a minimum, the information required under ADEM
Admin. Code r. 335-3-16-.05(c)(3). and the following
information, as applicable:
(i) Summary information on the number, duration
and cause (including unknown cause, if
applicable) of excursions or exceedances, as
applicable, and the corrective actions taken;
(ii) Summary information on the number, duration
and cause (including unknown cause, if
applicable) for monitor downtime incidents
(other than downtime associated with zero and
span or other daily calibration checks, if
applicable); and
14
General Permit Provisos
Federally Enforceable Provisos Regulations
(iii) A description of the actions taken to implement
a QIP during the reporting period as specified in
Section 33(b) above. Upon completion of a QIP,
the owner or operator shall include in the next
summary report documentation that the
implementation of the plan has been
completed and reduced the likelihood of similar
levels of excursions or exceedances occurring.
(2) General recordkeeping requirements
A. The owner or operator shall comply with the
recordkeeping requirements specified in ADEM Admin.
Code r. 335-3-16-.05(c)(2). The owner or operator shall
maintain records of monitoring data, monitor
performance data, corrective actions taken, any written
quality improvement plan required pursuant to Section
33(b) above and any activities undertaken to
implement a quality improvement plan, and other
supporting information required to be maintained
under this part (such as data used to document the
adequacy of monitoring, or records of monitoring
maintenance or corrective actions).
B. Instead of paper records, the owner or operator may
maintain records on alternative media, such as
microfilm, computer files, magnetic tape disks, or
microfiche, provided that the use of such alternative
media allows for expeditious inspection and review,
and does not conflict with other applicable
recordkeeping requirements.
(d) Savings Provisions 40 CFR 64.10
(1) Nothing in this part shall:
A. Excuse the owner or operator of a source from
compliance with any existing emission limitation or
standard, or any existing monitoring, testing, reporting
or recordkeeping requirement that may apply under
federal, state, or local law, or any other applicable
requirements under the Act. The requirements of this
part shall not be used to justify the approval of
monitoring less stringent than the monitoring which is
required under separate legal authority and are not
intended to establish minimum requirements for the
purpose of determining the monitoring to be imposed
15
General Permit Provisos
Federally Enforceable Provisos Regulations
under separate authority under the Act, including
monitoring in permits issued pursuant to title I of the
Act. The purpose of this part is to require, as part of the
issuance of a permit under title V of the Act, improved
or new monitoring at those emissions units where
monitoring requirements do not exist or are inadequate
to meet the requirements of this part.
B. Restrict or abrogate the authority of the Department to
impose additional or more stringent monitoring,
recordkeeping, testing, or reporting requirements on
any owner or operator of a source under any provision
of the Act, including but not limited to sections
114(a)(1) and 504(b), or state law, as applicable.
C. Restrict or abrogate the authority of the Department to
take any enforcement action under the Act for any
violation of an applicable requirement or of any person
to take action under section 304 of the Act.
34. Permit Shield Rule 335-3-16-.10
A permit shield exists under this operating permit in accordance with ADEM
Admin. Code 335-3-16-.10 in that compliance with the conditions of this permit
shall be deemed in compliance with any applicable requirements as of the date
of permit issuance. The permit shield is based on the accuracy of the
information supplied in the application for this permit. Under this shield, it has
been determined that requirements listed as non-applicable in the application
are not applicable to this source.
16
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17
Summary Page for Pre-Black Warrior Expansion Units: Process Heaters &
Boilers
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule= 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT * REGULATIONS
APPLIES TO EACH PROCESS HEATER LISTED BELOW: SO2 LIMITED BY FUEL GAS CONTENT:
When burning fuel gas:
H2S <= 162 ppmv
(3-hour averaging period)
OR
When burning fuel oil:
S <= 0.05 Wt%
§60.104(a)(1)
[NSPS J]
Rule 335-3-16-.05(a)
APPLIES TO EACH PROCESS HEATER, EXCEPT UNIT NO.:
T-14, T-33, T-50, AND REFORMER HEATERS: HS-
2401A, B, AND C
HAPs
Work Practice Standard §63.7485, §63.7490(a)(1),
(d), §63.7500(a)(1), (e),
[Boiler MACT]
APPLIES TO EACH PROCESS HEATER LISTED BELOW: Opacity No more than one 6 min avg. >
20%
AND
No 6 min avg. > 40% in any sixty
(60) minute period
Rule 335-3-4-.01(1)(a)
Rule 335-3-4-.01(1)(b)
CRUDE UNIT:
H-501X 155.50 MMBTU/Hour
Atmospheric Tower Charge
Heater—with:
NOX CEMS
&
NEXT GENERATION ULTRA LOW-NOX
BURNERS (NGULNB)
PM10 23.30 Lb/Hour Rule 335-3-4-.03(1)
NOX 0.03 Lb/MMBTU (HHV) @ 0%
excess air
(365 day Rolling Average)
Rule 335-3-16-.05(a)
H-501 26.0 MMBTU/Hour Vacuum
Tower Charge Heater with a
maximum firing rate of 26.0
MMBtu/hr
PM10 8.6 Lb/Hour Rule 335-3-4-.03(1)
NOX 0.15 Lb/MMBTU (HHV) Rule 335-3-16-.05(a)
H-503 32.55 MMBTU/Hour Naphtha
Fractionator Reboiler Heater
PM10 9.70 Lb/Hour Rule 335-3-4-.03(1)
ASPHALT OXIDATION UNIT:
T-14 4.7 MMBTU/Hour Asphalt
Blowing Still Burner
PM10 2.35 Lb/Hour Rule 335-3-4-.03(1)
T-33 2.0 MMBTU/Hour Asphalt
Blowing Still Burner
PM10 1.00 Lb/Hour Rule 335-3-4-.03(1)
18
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT * REGULATIONS
T-50 4.7 MMBTU/Hour Asphalt
Blowing Still Burner
PM10 2.35 Lb/Hour Rule 335-3-4-.03(1)
AX 15.33 MMBTU/Hour General
Asphalt Process Heater
PM10 6.36 Lb/Hour Rule 335-3-4-.03(1)
DISTILLATE/NAPHTHA HYDROTREATING UNIT:
H-H1 12.76 MMBTU/Hour Naphtha
Unifier Charge Heater
PM10 5.74 Lb/Hour Rule 335-3-4-.03(1)
H-H2 11.37 MMBTU/Hour Naphtha
Unifier Stripper Reboiler
Heater
PM10 5.38 Lb/Hour Rule 335-3-4-.03(1)
STODDARD UNIT:
HRC-039 8.73 MMBTU/Hour Stoddard
Tower Reboiler Heater
PM10 4.37 Lb/Hour Rule 335-3-4-.03(1)
KEROSENE HYDROTREATING UNIT:
P-H1 6.87 MMBTU/Hour Kerosene/
Naphtha Unifier Charge Heater
PM10 3.44 Lb/Hour Rule 335-3-4-.03(1)
P-H2 5.53 MMBTU/Hour Kerosene/
Naphtha Unifier Reboiler
Heater
PM10 2.77 Lb/Hour Rule 335-3-4-.03(1)
NO. 1 PLATFORMER:
H-502 28.1 MMBTU/Hour Platformer
Charge Heater
PM10 8.93 Lb/Hour Rule 335-3-4-.03(1)
P-H3B 8.79 MMBTU/Hour Platformer
No. 1 Interheater
PM10 4.40 Lb/Hour Rule 335-3-4-.03(1)
P-H3C 2.48 MMBTU/Hour Platformer
No. 2 Interheater
PM10 1.24 Lb/Hour Rule 335-3-4-.03(1)
UTILITY BOILERS:
B-01 37.14 MMBTU/Hour No. 1
Boiler
PM10 10.40 Lb/Hour Rule 335-3-4-.03(1)
B-02 37.14 MMBTU/Hour No. 2
Boiler
PM10 10.40 Lb/Hour Rule 335-3-4-.03(1)
B-03 37.14 MMBTU/Hour No. 3
Boiler
PM10 10.40 Lb/Hour Rule 335-3-4-.03(1)
B-04 74.0 MMBTU/Hour No. 4 Boiler PM10 15.40 Lb/Hour Rule 335-3-4-.03(1)
NOX 0.11 Lb/MMBTU (HHV) Rule 335-3-16-.05(a)
B-06 99.9 MMBTU/Hour No. 6 Boiler PM10 18.20 Lb/Hour Rule 335-3-4-.03(1)
NOX 11.4 Lb/Hour Rule 335-3-14-.04
[Anti-PSD Limit]
19
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT * REGULATIONS
COKE PULVERIZING UNIT:
FRN-22970 9.50 MMBTU/Hour Pulverizer
Dryer Heater
PM10 4.87 Lb/Hour Rule 335-3-4-.03(1)
NOX 3.14 Lb/Hour Rule 335-3-14-.04
[Anti-PSD Limit]
NAPHTHA HYDROBON UNIT:
HS-601 16.5 MMBTU/Hour Naphtha
Hydrobon Charge Heater
PM10 6.63 Lb/Hour Rule 335-3-4-.03(1)
HS-602 13.9 MMBTU/Hour Naphtha
Hydrobon Stripper Reboiler
Heater
PM10 6.03 Lb/Hour Rule 335-3-4-.03(1)
FLEXIBLE HYDROTREATER UNIT [FEEDRATE LIMITED TO 8,400 BBL/DAY (RULE 335-3-14-.04) [ANTI-PSD LIMIT]]
HS-201 29.1 MMBTU/Hour Naphtha
Hydrotreater Charge Heater
PM10 9.11 Lb/Hour Rule 335-3-4-.03(1)
HS-202 14.6 MMBTU/Hour Naphtha
Hydrotreater Reboiler Heater
PM10 6.19 Lb/Hour Rule 335-3-4-.03(1)
HYDROGEN PLANT NO. 1
THREE (3) REFORMER HEATERS W/COMMON STACK
HS-2401A
HS-2401B
HS-2401C
42.06 MMBTU/Hour Hydrogen
Plant Reformer A
PM10
NOX
20.1 Lb/Hour
4.42 Lb/Hour
Rule 335-3-4-.03(1)
Rule 335-3-14-.04
[Anti-PSD Limit] 42.06 MMBTU/Hour Hydrogen
Plant Reformer B
42.06 MMBTU/Hour Hydrogen
Plant Reformer C
ISOMERIZATION UNIT:
HS-104 12.9 MMBTU/Hour Stabilizer
Reboiler Heater
PM10 5.78 Lb/Hour Rule 335-3-4-.03(1)
DIESEL HYDROTREATING UNIT [DHT] [TOTAL FIRING RATE LIMITED TO 34.9 MMBTU/HR OVER 12 MONTH PERIOD [ANTI-PSD LIMIT]
TWO (2) HEATERS W/COMMON STACK
H-700
H-701
26.17 MMBTU/Hour DHT
Charge Heater
PM10
NOX
10.1 Lb/Hour
7.8 Lb/Hour
Rule 335-3-4-.03(1)
Rule 335-3-14-.04
[Anti-PSD Limit] 38.83 MMBTU/Hour DHT
Fractionator Reboiler Heater
20
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT * REGULATIONS
33,500 BBL/DAY DELAYED COKING UNIT [BA-602M FIRING RATE LIMITED TO 65.0 MMBTU/HR OVER 12 MONTH PERIOD
[PSD/BACT LIMIT]
TWO (2) COKER HEATERS W/COMMON STACK AND NGULNB
BA-601M
BA-602M
57.0 MMBTU/Hour Coker Drum
Charge Heater
PM10
NOX
SO2
18.8 Lb/Hour
0.025 Lb/MMBTU (HHV)
LIMITED BY FUEL GAS CONTENT:
When burning fuel gas:
H2S <= 162 ppmv based on a
three-hour rolling average
AND
H2S <= 59 ppmv based on a 365
consecutive day rolling average
Rule 335-3-4-.03(1)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
§60.104(a)(1)
[NSPS J]
Rule 335-3-14-.04
[Anti-PSD Limit]
65.0 MMBTU/Hour Coker
Drum Charge Heater
Opacity No more than one 6 min avg. >
10%
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
*Limits for each heater except as specified
21
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Applicability
Each process heater and boiler on the summary page of this subpart shall
be subject to the applicable requirements of ADEM Admin. Code r. 335-3-
4-.01, “Visible Emissions”, and the requirements specified in this subpart
of this permit, except as specified.
Rule 335-3-4-.01
Each process heater and boiler on the summary page of this subpart shall
be subject to the requirements of ADEM Admin. Code r. 335-3-4-.03, “Fuel
Burning Equipment” for Control of Particulate Emissions and the
requirements specified in this subpart of this permit.
Rule 335-3-4-.03(1)(a)
The Flexible Hydrotreater Unit, process heater Nos.: HS-2041A, HS-2041B,
HS-2041C, H-700, H-701, FRN-22970, BA-601M, BA-602M and boiler No.
B-06 each have limits in place in order to avoid a review under ADEM
Admin. Code r. 335-3-14-.04, “Air Permits Authorizing Construction in
Clean Air Areas [Prevention of Significant Deterioration (PSD)]”, and are
subject to the requirements specified in this subpart of this permit.
Rule 335-3-14-.04
[Anti-PSD Limit]
Process heaters: BA-601M and BA-602M have best available control
technology (BACT) limits in place to comply with the requirements
specified in ADEM Admin. Code r. 335-3-14, “Prevention of Significant
Deterioration (PSD)”, and the requirements specified in this subpart of
this permit.
Rule 335-3-14-.04(8)(a) &
(b)
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
Each boiler and process heater on the summary page of this subpart shall
be subject to the requirements specified in ADEM Admin. Code r. 335-3-
16-.03, “Major Source Operating Permits”, and the requirements specified
in this subpart of this permit.
Rule 335-3-16-.03
Boiler No. B-06 shall be subject to the requirements specified in 40 CFR
Part 60, Subpart A, “General Provisions”, 40 CFR 60 Subpart Dc, “Standards
of Performance for Small Industrial-Commercial-Institutional Steam
Generating Units”, and the requirements specified in this subpart of this
permit.
Rule 335-10-.02(2)(c)
§60.40c(a), (h)
Each process heater and boiler on the summary page of this subpart shall
be subject to the requirements specified in 40 CFR Part 60, Subpart A,
“General Provisions”, 40 CFR Part 60, Subpart J, “Standards of
Performance for Petroleum Refineries” [NSPS J], and the requirements
specified in this subpart of this permit.
40 CFR 60 Subpart A
40 CFR 60 Subpart J
Rule 335-3-16-.05(a)
Each boiler and process heater listed on the summary page of this
subpart, except units: T-14, T-33 and T-50 and reformer heaters: HS-
2401A, B, and C , shall be subject to the requirements specified in 40 CFR
Part 63, Subpart A “General Provisions”, 40 CFR 63 Subpart DDDDD,
“National Emission Standards for Hazardous Air Pollutants for Major
§63.7485,
§63.7490(a)(1),(d)
§63.7491(i)
§63.7499(p)
§63.7565
Table 10, Boiler MACT
22
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Sources: Industrial, Commercial, and Institutional Boilers and Process
Heaters” [Boiler MACT] for existing sources, and the requirements
specified in this subpart of this permit.
Emission Standards
Visible emissions from each process heater and boiler, except those
specified in proviso 1 (c) of this subpart, shall meet the opacity standards
specified in proviso 1(a) and (b) of this section of this subpart.
Rule 335-3-4-.01
Each process heater and boiler shall not discharge into the
atmosphere particulate that results in an opacity greater than
20%, as determined by a 6-minute average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-minute period,
each process heater and boiler shall not discharge into the
atmosphere particulate that results in an opacity greater than
40%.
Rule 335-3-4-.01(1)(b)
Process heaters: BA-601M and BA-602M shall not discharge into
the atmosphere particulate that results in an opacity greater than
10%, as determined by a 6-minute average, except for one 6-
minute period during any 60-consecutive minute period.
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
Rule 335-3-16-.05(a)
Particulate Matter (PM) emissions limits shall be met for the following
units:
Rule 335-3-4-.03(1)(a)
Rule 335-3-16-.05(a)
For process heater H-503, PM10 emissions shall be maintained at
less than, or equal to, 9.7 Lb/hr.
For process heater HS-201, PM10 emissions shall be maintained at
less than, or equal to, 9.11 Lb/hr.
For process heater HS-202, PM10 emissions shall be maintained at
less than, or equal to, 6.19 Lb/hr.
For process heaters T-14 and T-50, PM10 emissions for each heater
shall each be maintained at less than, or equal to, 2.35 Lb/hr.
For process heater T-33, PM10 emissions shall be maintained at
less than, or equal to, 1.00 Lb/hr.
For process heater AX, PM10 emissions shall be maintained at less
than, or equal to, 6.36 Lb/hr.
For process heater HS-601, PM10 emissions shall be maintained at
less than, or equal to, 6.63 Lb/hr.
23
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
For process heater HS-602, PM10 emissions shall be maintained at
less than, or equal to, 6.03 Lb/hr.
For process heater H-H1, PM10 emissions shall be maintained at
less than, or equal to, 5.74 Lb/hr.
For process heater H-H2, PM10 emissions shall be maintained at
less than, or equal to, 5.38 Lb/hr.
For process heater HRC-039, PM10 emissions shall be maintained
at less than, or equal to, 4.37 Lb/hr.
For process heater P-H1, PM10 emissions shall be maintained at
less than, or equal to, 3.44 Lb/hr.
For process heater P-H2, PM10 emissions shall be maintained at
less than, or equal to, 2.77 Lb/hr.
For process heater H-502, PM10 emissions shall be maintained at
less than, or equal to, 8.93 Lb/hr.
For process heater P-H3B, PM10 emissions shall be maintained at
less than, or equal to, 4.40 Lb/hr.
For process heater P-H3C, PM10 emissions shall be maintained at
less than, or equal to, 1.24 Lb/hr.
For boilers: B-01, B-02, and B-03, PM10 emissions for each boiler
shall each be maintained at less than, or equal to, 10.4 Lb/hr.
For process heater HS-104, PM10 emissions shall be maintained at
less than, or equal to, 5.78 Lb/hr.
The total feed to the Flexible Hydrotreater Unit shall not exceed 8,400
BBL/Day.
Rule 335-3-14-.04
[Anti-PSD Limit]
Process heaters BA-601M and BA-602M shall be subject to the following
requirements:
(a) Each process heater shall not combust fuel gas that contains
hydrogen sulfide (H2S) in excess of:
162 parts per million volume (ppmv) as determined
hourly on a three-hour rolling average basis,
AND
Rule 335-3-16-.05(a)
§60.104(a)(1)
24
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
59 ppmv as determined daily on a 365 consecutive day
rolling average basis.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
The following emission limitations shall apply:
PM10 emissions from the common stack shall be
maintained at less than, or equal to, 18.8 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
Nitrogen oxide (NOX) emissions from the common stack
shall be maintained at less than, or equal to, 0.025
Lb/MMBTU high heating value (HHV).
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
The firing rate for process heater BA-602M shall be
limited to 65.0 MMBTU/hr, as averaged over a 12-month
period.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
The following emission standards shall be met for the emission units listed
below:
For process heater H-501X:
PM10 emissions shall be maintained at less than, or equal
to, 23.30 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or equal
to, 0.03 Lb/MMBTU (HHV) at zero percent (0%) excess air
over a 365-day rolling average period.
Rule 335-3-16-.05(a)
Shall be equipped with a NOX continuous emissions
monitoring system (CEMS) and next generation ultra-low
NOX burners (NGULNB).
Rule 335-3-16-.05(a)
For process heater H-501:
PM10 emissions shall be maintained at less than, or equal
to, 8.6 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or equal
to, 0.15 Lb/MMBTU (HHV).
Rule 335-3-16-.05(a)
This heater shall be operated and maintained such that
the maximum firing rate is 26.0 MMBTU/hr, as averaged
over a 12-month period.
Rule 335-3-16-.05(a)
25
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
For process heater FRN-22970:
PM10 emissions shall be maintained at less than, or equal
to, 4.87 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or equal
to, 3.14 Lb/hr.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
For boiler B-04:
PM10 emissions shall be maintained at less than, or equal
to, 15.4 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or equal
to, 0.11 Lb/MMBTU (HHV).
Rule 335-3-16-.05(a)
For boiler B-06:
PM10 emissions shall be maintained at less than, or equal
to, 18.2 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or equal
to, 11.4 Lb/hr.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
For the common stack for process heaters HS-2401A, HS-2401B,
& HS-2401C:
PM10 emissions from the common stack shall be
maintained at less than, or equal to, 20.1 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions from the common stack shall be
maintained at less than, or equal to, 4.42 Lb/hr.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
For the common stack for process heaters H-700 & H-701:
PM10 emissions from the common stack shall be
maintained at less than, or equal to, 10.1 Lb/hr.
Rule 335-3-4-.03(1)
Rule 335-3-16-.05(a)
NOX emissions from the common stack shall be
maintained at less than, or equal to, 7.8 Lb/hr.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
The total firing rate for process heaters H-700 and H-701
shall be limited to 34.9 MMBTU/hr, as averaged over a
12-month period.
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(a)
26
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The following fuel gas requirements shall be met:
Each boiler or process heater shall not combust fuel gas that
contains H2S in excess of 162 ppmv as determined hourly on a
three-hour rolling average basis.
§60.104(a)(1)
Rule 335-3-16-.05(a)
Fuel oil with a maximum sulfur (S) content of 0.05 weight percent
(wt%) may only be burned during periods of fuel gas curtailment
for boilers: B-01, B-02, B-03, and B-04.
Rule 335-3-16-.05(a)
Except as allowed in §63.7500(b), the following work practice standards
(WPS) shall be met in order for affected units to comply with the Boiler
MACT:
§63.7495(b)
§63.7500(b)
Each boiler and process heater must be designed to burn gas 1
fuel such as natural gas, refinery gas and/or other gas 1 fuels.
§63.7499(l), §63.7500(e)
§63.7575
A performance tune-up shall be completed on each boiler and
process heater as specified in §63.7540.
§63.7500(a),(e)
§63.7515(d), §63.7540
Table 3 Boiler MACT
Each boiler and process heater must be operated and maintained,
including associated air pollution control equipment and
monitoring equipment, in a manner consistent with safety and
good air pollution control practices for minimizing emissions.
§63.7500(a)(3)
Rule 335-3-16-.05(a)
The WPS must be met at all times that a boiler or process heater
is operating.
§63.7505(a)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards shall be determined using Method
9 or Method 22 of 40 CFR part 60, Appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
Each boiler and/or process heater that is subject to performance testing
shall be tested in accordance with the following test methods and
procedures:
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-1, Method 1 or 1A to determine the
sampling site
Rule 335-3-1-.05
40 CFR Part 60, Appendix A-1, Method 2 or 2A or 2B or 2C or 2D
or 2E to determine the volumetric flow rate of the effluent gas
Rule 335-3-1-.05
40 CFR Part 60, Appendix A-2, Method 3 or 3A or 3B or 3C to
determine the gas analysis
Rule 335-3-1-.05
27
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
40 CFR Part 60, Appendix A-3, Method 4 to determine the
moisture in the stack gas
Rule 335-3-1-.05
40 CFR Part 60, Appendix A-4, Method 7 OR 7A OR 7B OR 7C OR
7D OR 7E to determine NOX emissions
Rule 335-3-1-.05
40 CFR Part 60, Appendix A-7, Method 19 to determine PM, sulfur
dioxide (SO2) and NOX emissions
Rule 335-3-1-.05
The NOX continuous emission monitoring system (CEMS) on process
heater H-501X must be maintained in accordance with the following
requirements:
40 CFR §60.13 (excluding continuous opacity monitoring systems)
40 CFR Part 60, Appendices A and F
Applicable performance specifications of 40 CFR Part 60,
Appendix B
Rule 335-3-16-.05(a)
The fuel gas system shall comply with the following test requirements:
Shall be analyzed for its BTU heat content by utilizing the ASTM
Analysis Method D1826-77 or equivalent method
[Fuel Gas Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(1)(ii)
The relative accuracy evaluations for the H2S monitor shall be
conducted using the following methods and procedures:
§60.106(e)(1)
Performance Specification 7 as specified in 40 CFR Part
60, Appendix B
§60.105(a)(4)(iii)
40 CFR Part 60, Appendix A, Method 11, 15, 15A or 16 as
specified in §60.106(e)(1)(i) through (iii)
§60.105(a)(4)(iii)
§60.106(e)(1)
Compliance with the Boiler MACT shall be demonstrated by conducting
tune-ups on each applicable process heater and boiler as specified in
§63.7540(a)(10)(i) through (vi) of the Boiler MACT.
§63.7540(a)(10)
Emission Monitoring
Provided that visible emissions in excess of the opacity standards occur
on a unit, a visible emissions observation must be conducted to determine
opacity or to determine presence of fugitive emissions from the unit.
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
28
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The following requirements shall be met for performance testing
conducted on process heaters: H-700, H-701, BA-601M, BA-602M, H-501,
on the common stack for HS-2041A, B, C and on boilers: B-04 and B-06:
Rule 335-3-16-.05(c)(1)(i)
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
Test for NOX emissions once every five (5) years in accordance
with the Heating Units Subject to NOX Testing section found in
Appendix A of this permit.
A test shall consist of three runs of at least 1-hour in duration
each.
The results of performance tests shall be submitted to the
Department within 30 days of the test date.
The pollutant tested for may be modified upon receiving
Departmental approval.
Emission factors (EF) for each air pollutant shall be determined in
pounds per million BTU.
[Test EF (Lb/MMBTU)]
Process heater H-501X shall be equipped with a NOX CEMS. Rule 335-3-16-.05(a)
Rule 335-3-16-.05(c)(1)(ii)
The CEMS shall be monitored in accordance with the Heating
Units with NOX CEMS section found in Appendix A of this permit.
In lieu of the requirements of 40 CFR Part 60, Appendix F, §§5.1.1,
5.1.3, and 5.1.4, either a Relative Accuracy Audit (RAA) or a
Relative Accuracy Test Audit (RATA) must be conducted on the
CEMS at least once every three (3) years.
A cylinder gas audit (CGA) must be conducted each calendar
quarter during which a RAA or a RATA in not performed.
The Flexible Hydrotreater Unit feedrate limit and the firing rate limits for
H-700 & H-701, H-501, and BA-602M shall be demonstrated through
monthly calculations.
Rule 335-3-16-.05(c)(1)(ii)
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
The fuel gas system must meet the following requirements:
A H2S fuel gas monitor that continuously monitors and records the
concentration (dry basis) of H2S in the fuel gas before being
burned in any fuel gas combustion devices shall be installed,
Rule 335-3-16-.05(c)(1)(ii)
§60.105(a)(4)
§60.13
29
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
calibrated, maintained and operated as specified in §60.105(a)(4)
[NSPS J] and §60.13 of Subpart A.
Relative accuracy evaluations must be conducted on the fuel gas
system CEMS used to determine the H2S concentration. A CGA
must be conducted each calendar quarter during which a RAA or
a RATA in not performed.
§60.13(a)
Rule 335-3-16-.05(a)
Process heaters and boilers with a common source of fuel gas may
be monitored at only one location if that location accurately
represents the H2S concentration of the fuel being burned.
§60.105(a)(4)(ii)
BTU heat content testing shall consist of capturing a
representative sample of the fuel gas stream at a frequency of no
less than once each month.
[Fuel Gas Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(1)(ii)
The frequency of analysis may be modified upon receiving
Departmental approval.
Rule 335-3-16-.05(c)(1)(ii)
The following monitoring requirements shall be met to comply with the
WPS for affected sources designed to burn gas 1 fuels subcategory under
the Boiler MACT:
Each process heater and boiler with a heat input capacity greater
than or equal to 10 million Btu per hour (MMBTU/hr) must
complete a tune-up annually as specified in §63.7540(a)(10).
Subsequent tune-ups must occur no more than thirteen (13)
months after the previous tune-up.
§63.7510(e)
§63.7515(d)
§63.7540(a)(10)
Each process heater and boiler with a heat input capacity greater
than 5 MMBtu/hr and less than 10 MMBTU/hr must complete a
tune-up every two (2) years or biennially as specified in
§63.7540(a)(10). Subsequent tune-ups must occur no more than
twenty-five (25) months after the previous tune-up.
§63.7500(e)
§63.7510(e)
§63.7515(d)
§63.7540(a)(11)
Each process heater and boiler with a heat input capacity less
than or equal to 5 MMBTU/hr must complete a tune-up every five
(5) years as specified in §63.7540(a)(10). Subsequent tune-ups
must occur no more than sixty-one (61) months after the previous
tune-up.
§63.7500(e)
§63.7510(e)
§63.7515(d)
§63.7540(a)(12)
30
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The following requirements must be met for each tune-up:
Each tune-up must be conducted while burning the type
of fuel that provided the majority of the heat input to the
unit over the 12 months prior to the tune-up.
§63.7540(a)(10)
Annual tune-ups do not apply to units with continuous
oxygen trim systems that maintain an optimum air to fuel
ratio.
§63.7540(a)(10)
For units with oxygen trim or less than 5 MMBtu/hr,
burner inspections may be delayed until the next
scheduled or unscheduled unit shutdown; however, you
must inspect each burner at least once every seventy-two
(72) months.
§63.7540(a)(12)
If an oxygen trim system is utilized on a unit without
emission standards to reduce the tune-up frequency to
once every five (5) years, set the oxygen level no lower
than the oxygen concentration measured during the most
recent tune-up.
§63.7540(a)(12)
If the unit is not operating on the required date for a tune-
up, the tune-up must be conducted within 30 calendar
days of startup.
§63.7540(a)(13)
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (n) of this
section of this subpart shall be maintained and made available for
inspection. These records may be in electronic format provided they are
readily accessible.
The date, starting time and duration of each deviation from the
requirements specified in this subpart along with the cause and
corrective actions taken.
Rule 335-3-16-.05(c)(2)
§63.7560
The date, time, and results of each performance test along with
any other tests conducted on the boiler and/or process heater
that provides additional stack pollutant content data.
Rule 335-3-16-.05(c)(2)
Date and type of boiler or process heater maintenance that
affects air emissions shall be maintained.
Rule 335-3-16-.05(c)(2)
Fuel gas BTU heat content
[Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(2)
31
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Fuel gas H2S content
[H2S Content (Mole %)]
Rule 335-3-16-.05(c)(2)
§60.48c(f)(4)
§60.105(a)(4)
Fuel gas consumption rate per unit
[Volume (Mscf/Month)]
Rule 335-3-16-.05(c)(2)
§60.48c(g)(2)
For all units, except asphalt burners: T-14, T-33, and T-50,
this consumption rate shall be recorded by a continuous
monitor on each unit.
For asphalt burners: T-14, T-33, and T-50, this
consumption rate shall be based on design specifications,
engineering calculations, and/or a continuous monitor.
MMBTU of fuel gas consumption per unit: Rule 335-3-16-.05(c)(2)
Unit Fuel Gas Heat Input (MMBTU/Month) =
[ Volume (Mscf/Month)] X [ Heat Content (BTU/scf) ]
{1,000}
A running total of hours per calendar year when a fuel other than
natural gas or other gas-1 fuel is burned in a process heater
and/or boiler shall be maintained.
§63.7555(h)
Operating hours per unit
[Unit Hours (Hours/Month)]
Rule 335-3-16-.05(c)(2)
Monthly NOX emissions shall be determined for process heater H-
501, process heater H-503, process heater AX, the combined stack
for process heaters H-700 & H-701, the combined stack for
process heaters HS-2401A, HS-2401B, & HS-2401C, the combined
stack for process heaters BA-601M & BA-602M, boiler B-04, and
boiler B-06 as follows:
Rule 335-3-16-.05(c)(2) &
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
Unit Emissions (Lb/Month) =
[Unit Heat Input (MMBTU/Month)] X [Test EF (Lb/MMBTU)]
(i) For units subject to emissions testing, [Test
emission factors (Lb/MMBTU)] shall be taken
from the most recent performance test.
32
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
(ii) For all other units, [Test emission factors
(Lb/MMBTU)] shall be either AP-42 emissions
factors, or manufacturer’s emission factors.
Unit Emissions (Lb/Hour) =
[ Unit Emissions (Lb/Month) ]
[ Unit Hours (Hours/Month) ]
For the common stack for process heaters H-700 & H-701, H-501
and process heater BA-602M:
Rule 335-3-16-.05(c)(2)
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
Process Unit Operating hours
[ Process Hours (Hours/Month) ]
Monthly Average Firing Rate [MMBTU/hr] =
[Unit Heat Input (MMBTU/Month)]
[Process Hours (Hours/Month)]
Total Annual Firing Rate [MMBTU/hr] =
Monthly Average Firing Rate [MMBTU/hr] +
∑ previous 11-months Average Firing Rate [MMBTU/hr]
Annual Average Firing Rate [MMBTU/hr] =
Total Annual Firing Rate [MMBTU/hr]
12-Months
For the Naphtha Hydrotreating [NH] Unit: Rule 335-3-16-.05(c)(2)
Rule 335-3-14-.04
[Anti-PSD Limit]
Naphtha Processed
[BBL/Month]
NH Operating Time
[Days/Month]
Daily Average Naphtha Processed [BBL/Day] =
Naphtha Processed [BBL/Month]
NH Operating Time [Days/Month]
Total Naphtha Processed [BBL/Day] =
Daily Average Naphtha Processed [BBL/Day] + ∑ previous 11-months Daily
Average Naphtha Processed [BBL/Day]
33
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Total Average Naphtha Processed [BBL/Day] =
Total Naphtha Processed [BBL/Day]
12-Months
A copy of the NOX CEMS monitoring record for process heater H-
501X shall be maintained onsite in a form suitable for inspection.
Rule 335-3-16-.05(c)(2)
A record of each visible emission observation conducted on a unit. Rule 335-3-16-.05(c)(2)
To demonstrate compliance with NSPS J, the following reporting
requirements shall be met:
Rule 335-3-16-.05(c)(2)
An excess emissions report and/or summary report shall be
submitted semi-annually on the following reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1 - December 31 February 28
§60.7(c), (d),
§60.19(d), (e)
The excess emission report shall include each rolling 3-hr period
during which the average H2S concentration in the fuel gas
(measured using the continuous H2S monitor) exceeds its
allowable.
§60.105(e)(3)(ii)
The information specified in §60.7(c) of Subpart A and §60.107(g)
of NSPS J shall be provided in each excess emissions report.
§60.105(e)
§60.107(g)
To demonstrate compliance with the Boiler MACT, the following
requirements shall be met:
The following notifications shall be submitted: §63.7545
Notifications specified in §63.7545(a) of the Boiler MACT §63.7545(a)
Notification of alternative fuel usage during periods of
natural gas curtailment or supply interruption shall be
submitted within forty-eight (48) hours of the declaration
of such period
§63.7545(f)
The following records shall be maintained: §63.7555
A copy of each notification and report to comply with this
subpart according to §63.10(b)(2)(xiv) of Subpart A
§63.7555(a)(1)
Records of compliance demonstrations as required by
§63.10(b)(2)(viii) of Subpart A
§63.7555(a)(2)
34
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
If an alternative fuel is used in the boilers or process
heaters during periods of gas curtailment or gas supply
emergencies, the following records shall be maintained:
§63.7555(h)
(i) Record of the total hours per calendar year that
the alternative fuel is burned
(ii) Record of the total hours per calendar year that
the unit operated during periods of gas
curtailment or gas supply emergencies.
A record of burner inspection shall be maintained for
units with delayed tune-ups
§63.7550(c)(5)(xiv)
Records must be kept and maintained as specified in §63.7560 of the
Boiler MACT for a period of five years following each occurrence.
§63.7560
The following reporting requirements shall be met: §63.7550
An annual, biennial, or 5-year compliance report shall be
submitted as specified in §63.7550(b)(1) through (3) of
the Boiler MACT, except as allowed in §63.7550(b)(4) of
the Boiler MACT.
§63.7550(b)
§63.10(a)(7)
The compliance report must contain the information
specified in §63.7550(c)(1) of the Boiler MACT.
§63.7550(c)(1)
The reports must be submitted electronically to the EPA
via CEDRI, except as allowed, and a copy of the report
must be submitted to the Department for tracking
purposes.
§63.7550(h)(3)
A periodic monitoring report (PMR) meeting the requirements specified
in proviso 4(a) and (b) of this section of this subpart shall be submitted to
the Department.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups and shutdowns.
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the permit
that can be used to determine or indicate compliance,
that identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
35
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
Except as provided for in proviso 4(c) of this section, the report
shall include the information specified in proviso 4(b)(1) of this
section of this subpart.
For each deviation event, the following information shall
be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period and
shall be submitted according to the following reporting
schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
36
Provisos for Pre-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The report content specified in proviso 4(b) of this section may be
modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
37
Summary Page for Post-Black Warrior Expansion Units: Process Heaters &
Boilers
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
APPLIES TO EACH PROCESS HEATER LISTED BELOW: SO2 LIMITED BY FUEL GAS
CONTENT:
When burning fuel gas:
H2S <= 162 ppmv
AND
H2S <= 59 ppmv based on
a 365-day consecutive
rolling avg.
40 CFR §60.102a(g)(1)
[NSPS Ja]
Rule 335-3-14-.04(9)
[Anti-PSD Limit]
APPLIES TO EACH PROCESS HEATER, EXCEPT REFORMER
HEATER, HP2-H-3600:
HAPs Work Practice Standard §63.7485, §63.7490(a)(2), (b),
§63.7500(a)(1), (e)
[Boiler MACT]
APPLIES TO EACH PROCESS HEATER LISTED BELOW: Opacity No more than one 6 min
avg. > 10%
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
33,500 BBL/DAY DELAYED COKING UNIT:
BA-603 198.0 MMBTU/Hour
Coker Pre-heater —with:
NOX CEMS
NGULNB
PM10 0.0075 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
NOX 0.025 Lb/MMBTU
@ 0% excess air
(30 Day Rolling Average)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
§60.102a(g)(2)
[NSPS Ja]
VOC 0.0054 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
22,200 BBL/DAY CONTINUOUS CATALYST REGENERATION [CCR] PLATFORMING UNIT:
Three (3) CCR Heaters w/ Common Stack, NOX CEMS, & NGULNB
CR-H-3801
CR-H-3802
CR-H-3803
69.3 MMBTU/Hour CCR
Platformer Charge Heater
78.2 MMBTU/Hour CCR
Interstage Heater No. 1
60.9 MMBTU/Hour CCR
Interstage Heater No. 2
PM10 0.0075 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
NOX 0.025 Lb/MMBTU (HHV)
@ 0% excess air
(30 Day Rolling Average)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
§60.102a(g)(2)
[NSPS Ja]
VOC 0.0054 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
38
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
31.9 MMSCF/DAY HYDROGEN PLANT NO. 2:
HP2-H-3600 254.0 MMBTU/hr No. 2
Hydrogen Plant
Reformer—with:
NOX CEMS
NGULNB
PM10 0.0075 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
NOX 0.035 Lb/MMBTU (HHV)
@ 0% excess air
(30 Day Rolling Average)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
40 CFR 60.102a(g)(2)
[NSPS Ja]
VOC 0.0054 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
30,000 BBL/DAY HYDROCRACKING UNIT:
Two (2) Hydrocracker Heaters w/ Common Stack, NOX CEMS, & NGULNB
HD-H-3401
HD-H-3402
60.28MMBtu/hr
Hydrocracker Reactor
Charge Heater
98.3 MMBtu/hr
Fractionator Feed Heater
PM10 0.0075 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
NOX 0.025 Lb/MMBTU (HHV)
@ 0% excess air
(30 Day Rolling Average)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
40 CFR 60.102a(g)(2)
[NSPS Ja]
VOC 0.0054 Lb/MMBTU Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
RAILCAR LOADING OPERATIONS:
B-07 59.8 MMBtr/hr Steam
Boiler with continuous
oxygen trim system
PM10 13.64 Lb/Hour Rule 335-3-4-.03(1)
Opacity No more than one 6 min
avg. > 20%
AND
No 6 min avg. > 40% in
any sixty (60) minute
period
Rule 335-3-4-.01(1)(a)
Rule 335-3-4-.01(1)(b)
SO2 LIMITED BY FUEL GAS
CONTENT:
When burning fuel gas:
H2S <= 162 ppmv based
on a 3-hour rolling avg.
AND
H2S ≤ 60 ppmv on a 365-
day consecutive rolling
avg.
40 CFR §60.102a(g)(1)(ii)
[NSPS Ja]
HAPs Work Practice Standard §63.7500(a)(1), (e), [Boiler
MACT]
39
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Applicability
Boiler No. B-07 shall be subject to the requirements of ADEM Admin.
Code r. 335-3-4-.03, “Fuel Burning Equipment” for Control of
Particulate Emissions and the requirements specified in this subpart of
this permit.
Rule 335-3-4-.03(1)(a)
Each process heater on the summary page of this subpart is subject to
a fuel gas limit in order to avoid a review under ADEM Admin. Code r.
335-3-14-.04, “Air Permits Authorizing Construction in Clean Air Areas
[Prevention of Significant Deterioration (PSD)]", and are subject to the
requirements specified in this subpart of this permit.
Rule 335-3-14-.04
[Anti-PSD Limit]
Each process heater on the summary page of this subpart shall have
best available control technology (BACT) limits in place to comply with
the requirements specified in ADEM Admin. Code r. 335-3-14,
“Prevention of Significant Deterioration (PSD)”, and the requirements
specified in this subpart of this permit.
Rule 335-3-14-.04(8)(a) & (b)
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
Each emission sources listed on the summary page of this subpart shall
be subject to the requirements specified in ADEM Admin. Code r. 335-
3-16-.03, “Major Source Operating Permits”, and the requirements
specified in this subpart of this permit.
Rule 335-3-16-.03
Boiler No. B-07 shall be subject to the requirements specified in 40 CFR
Part 60, Subpart A, “General Provisions”, 40 CFR 60 Subpart Dc,
“Standards of Performance for Small Industrial-Commercial-
Institutional Steam Generating Units”, and the requirements specified
in this subpart of this permit.
Rule 335-10-.02(2)(c)
§60.40c(a), (h)
Each emission source listed on the summary page of this subpart shall
be subject to the requirements specified in 40 CFR Part 60, Subpart A,
“General Provisions”, 40 CFR Part 60, Subpart Ja “Standards of
Performance for Petroleum Refineries” [NSPS Ja], and the
requirements specified in this subpart of this permit.
§60.100a(a)
§60.40c(h)
Each emission source listed on the summary page of this subpart,
except process heater HP2-H-3600, shall be subject to the
requirements specified in 40 CFR Part 63, Subpart A “General
Provisions”, 40 CFR 63 Subpart DDDDD, “National Emission Standards
for Hazardous Air Pollutants for Major Sources: Industrial, Commercial,
and Institutional Boilers and Process Heaters” [Boiler MACT], for new
sources, and the requirements specified in this subpart of this permit.
§63.7485,
§63.7490(a)(2), (b)
§63.7491(i)
§63.7499(p)
§63.7565
Table 10, Boiler MACT
40
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Emission Standards
The following opacity standards shall be met for the process heaters
and boilers:
(a) Each process heater shall not discharge into the atmosphere
particulate that results in an opacity greater than 10%, as
determined by a 6-minute average, except for one 6-minute
period during any 60-consecutive minute period.
Rule 335-3-16-.05(a)
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
(b) Boiler B-07 shall comply with the following opacity standards.
This unit shall not discharge into the atmosphere
particulate that results in an opacity greater than 20%,
as determined by a 6-minute average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-minute
period, this unit shall not discharge into the
atmosphere particulate that results in an opacity
greater than 40%.
Rule 335-3-4-.01(1)(b)
The following emission standards shall be met for the emission units
listed below:
For process heater BA-603, the common stack for heaters HD-
H-3401 & HD-H-3402, and the common stack for heaters CR-
H-3801, CR-H-3802, & CR-H-3803, the following limits shall
apply for each heater or common heater stack:
Particulate matter, PM10, emissions shall be
maintained at less than, or equal to, 0.0075
Lb/MMBTU.
Rule 335-3-4-.03(1)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
Nitrogen oxide (NOX) emissions shall be maintained at
less than, or equal to, 0.025 Lb/MMBTU high heating
value (HHV) at zero percent (0%) excess air averaged
over a 30-day period.
§60.102a(g)(2)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
Volatile organic compound (VOC) emissions shall be
maintained at less than, or equal to, 0.0054
Lb/MMBTU.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
For heater HP2-H-3600:
PM10 emissions shall be maintained at less than, or
equal to, 0.0075 Lb/MMBTU.
Rule 335-3-4-.03(1)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
41
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Rule 335-3-16-.05(a)
NOX emissions shall be maintained at less than, or
equal to, 0.035 Lb/MMBTU (HHV) at zero percent (0%)
excess air averaged over a 30-day period.
§60.102a(g)(2)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
VOC emissions shall be maintained at less than, or
equal to, 0.0054 Lb/MMBTU.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Rule 335-3-16-.05(a)
For Boiler B-07,
(1) PM10 emissions shall be maintained at less than, or
equal to, 13.64 Lb/Hour.
Rule 335-3-4-.03(1)
(2) Shall not combust fuel gas that contains H2S in excess
of:
§60.102a(g)(1)(ii)
§60.40c(h)
(i) 162 ppmv as determined hourly on a three-
hour rolling average basis
AND
(ii) 60 ppmv as determined on a 365-calendar
day consecutive rolling average
Each process heater or common stack shall be equipped with a NOX
continuous emission monitoring system (CEMS), including an oxygen
(O2) monitor and next generation ultra-low NOX burners (NGULNB).
§60.107a(d)(1)
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Each process heater shall meet the following fuel gas emission
standards:
Shall not combust fuel gas that contains H2S in excess of: Rule 335-3-5-.01(1)(b)
Rule 335-3-16-.05(a)
162 ppmv as determined hourly on a three hour-
rolling average basis
AND
§60.102a(g)(1)(ii)
59 ppmv as determined daily on a 365-calendar day
consecutive rolling average
Rule 335-3-14-.04
[Anti-PSD Limit]
An alternative means of emission limitation may be
established as specified in §60.103a(j)
§60.103a(j)
A root cause analysis and corrective action analysis shall be
conducted for each exceedance of an applicable short-term
emissions limit if the sulfur dioxide (SO2) discharged to
§60.103a(c)(2)
42
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
atmosphere is 227 kilograms (kg) (500 Lb) greater than the
amount that would have been emitted if the emission limits
had been met during one or more consecutive period of
excess emissions or any 24 hour period, whichever is shorter
Except as allowed in §63.7500(b), the following work practice
standards (WPS) shall be met to comply with the Boiler MACT for all
affected sources listed on the summary page of this subpart.
§63.7495(b)
§63.7500(b)
Each unit must be designed to burn gas 1 fuel such as natural
gas, refinery gas and/or other gas 1 fuels.
§63.7499(l), §63.7500(e)
§63.7575
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
A performance tune-up shall be completed on each unit as
specified in §63.7540.
§63.7500(a),(e)
§63.7515(d), §63.7540
Table 3 Boiler MACT
Each unit must be operated and maintained, including
associated air pollution control equipment and monitoring
equipment, in a manner consistent with safety and good air
pollution control practices for minimizing emissions.
§63.7500(a)(3)
WPS must be met at all times that a unit is operating. §63.7505(a)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards shall be determined using
Method 9 or Method 22 of 40 CFR part 60, appendix A.
Rule 335-3-1-.05
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
Rule 335-3-16-.05(a)
Except as specified in §60.8(b), performance testing, when applicable,
shall be conducted on each process heater in accordance with the
following test methods and procedures:
§60.104a (a) and (c)
§60.104a(i)
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-1, Method 1 to determine the
sample and velocity tranverses
§60.104a(i)(1)
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-1, Method 2 to determine the
velocity and volumetric flow rate
§60.104a(i)(2)
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-2, Method 3 OR 3A OR 3B to
determine the gas analysis. ANSI/ASME PTC 19.10-1981, “Flue
and Exhaust Gas Analyses,” (incorporated by reference-see
§60.17) is an acceptable alternative to EPA Method 3B
§60.104a(i)(3)
Rule 335-3-16-.05(c)(1)(i)
43
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
40 CFR Part 60, Appendix A-3, Method 4 to determine the
moisture in the stack gas
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-7, Method 19 to determine PM,
sulfur dioxide (SO2) and NOX emissions
Rule 335-3-16-.05(c)(1)(i)
40 CFR Part 60, Appendix A-6, Method 18 OR 40 CFR Part 60,
Appendix A-7, Method 25A OR 25B or 25C OR 25D OR 25E to
determine VOC emissions
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
NOX CEMS on the process heaters shall comply with the following
methods and procedures:
Performance evaluations shall be conducted in accordance
with §60.13(c) and Performance Specification (PS) 2 as
specified in 40 CFR Part 60, Appendix B.
§60.107a(c)(1)-(5), (d)
Relative accuracy evaluations shall be conducted using one of
the following methods and procedures:
§60.107a(c)(2)
40 CFR Part 60, Appendix A-4, Method 7 OR 7A OR 7C
OR 7D OR 7E to determine the moisture content and
NOX concentration calculated as NO2.
ANSI/ASME PTC 19.10-1981, “Flue and Exhaust Gas
Analyses,” (incorporated by reference-see §60.17) is
an acceptable alternative to 40 CFR Part 60, Appendix
A-4, Method 7 OR 7C
The F-factor of the fuel gas stream shall be determined using
the methods and procedures specified in §60.107a(d)(1)-(4).
§60.107a(d)
The O2 monitor shall comply with the following methods and
procedures:
§60.107a(c)(3)
Performance evaluations shall be conducted in
accordance with §60.13(c) and Performance
Specification 3 of 40 CFR Part 60, Appendix B.
§60.107a(c)(4)
Relative accuracy evaluations shall be conducted
using one of the following methods and procedures:
§60.107a(c)(4)
(i) 40 CFR Part 60, Appendix A-2, Method 3 OR
3A OR 3B
44
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
(ii) ANSI/ASME PTC 19.10-1981, “Flue and
Exhaust Gas Analyses,” (incorporated by
reference-see §60.17) is an acceptable
alternative to 40 CFR Part 60, Appendix A-2,
Method 3B
The quality assurance requirements in Procedure 1 of 40 CFR
Part 60, Appendix F shall be met for each NOX and O2 monitor.
§60.107a(c)(5)
The fuel gas system must meet the following requirements:
Shall be analyzed for its BTU heat content by utilizing the
ASTM Analysis Method D1826-77 or equivalent method.
[ Fuel Gas Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(1)(ii)
Performance evaluations shall be conducted on the H2S
monitor in accordance with §60.13(c) and Performance
Specification 7 as specified in 40 CFR Part 60, Appendix B.
§60.107a(a)(2)(ii)
Relative accuracy evaluations for the H2S monitor shall be
conducted using one of the following methods and
procedures:
§60.107a(a)(2)(ii)
40 CFR Part 60, Appendix A-5, Method 11 to
determine the H2S content of the fuel gas stream
40 CFR Part 60, Appendix A-5, Method 15 to
determine H2S emissions
40 CFR Part 60, Appendix A-5, Method 15A;
ANSI/ASME PTC 19.10-1981, “Flue and Exhaust Gas
Analyses,” (incorporated by reference-see §60.17) is
an acceptable alternative to EPA Method 15A
40 CFR Part 60, Appendix A-6, Method 16 to
determine sulfur emissions from stationary sources
The applicable quality assurance procedures in Appendix F of
Part 60, shall be met.
§60.107a(a)(2)(iii)
Compliance with the Boiler MACT shall be demonstrated by
conducting tune-ups on each process heaters as specified in
§63.7540(a)(10)(i) through (vi).
§63.7540(a)(10)
45
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Emission Monitoring
Provided that visible emissions in excess of the opacity standards
occur on a unit, a visible emissions observation must be conducted to
determine opacity or to determine presence of fugitive emissions
from the unit.
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
The following performance test requirements must be met to
determine emissions from each process heater or common stack:
Rule 335-3-16-.05(c)(1)(i)
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
Each unit shall be tested for VOC emissions once every five (5)
years in accordance with the Heating Units Subject to VOC
Testing section found in Appendix A of this permit.
A test shall consist of three runs of at least 1-hour in duration
each.
The results of performance tests shall be submitted to the
Department within 30 days of the test date.
Emission factors shall be determined in pounds per million
BTU.
[Test Emission Factors (Lbs/MMBTU)]
Each root cause analysis and corrective action analysis shall meet the
following requirements to demonstrate compliance with NSPS Ja:
Shall be completed as soon as possible, but no later than forty-
five (45) days after a discharge
§60.103a(d)
Special circumstances affecting the number of root cause
analyses and/or corrective action analyses are identified in
§60.103a(d)
§60.103a(d)
Corrective actions identified in the corrective action analysis
shall comply with the applicable requirements specified in
§60.103a(e)
§60.103a(e)
The NOX CEMS on each of the process heaters shall be installed,
operated, calibrated, and maintained as follows:
Shall continuously monitor and record the concentration (dry
basis, 0-percent excess air) of NOX emissions into the
atmosphere
§60.107a(d)
46
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The F-factor of the fuel gas stream shall be determined no less
frequently than once per day
§60.107a(d)
Must include an O2 monitor for correcting the data for excess
air
§60.107a(c)(2)
§60.107a(d)(1)
Shall be monitored in accordance with the Heating Units with
NOX CEMS section found in Appendix A of this permit.
Rule 335-3-16-.05(c)(1)(ii)
§60.13
A Relative Accuracy Test Audit (RATA) shall be conducted on
the NOX CEMS at least once every four calendar quarters as
specified in Part 60, Appendix F, Procedure 1, Section 5.1.2
§60.107a(c)(5)
Rule 335-3-16-.05(c)
A Cylinder Gas Audit shall be conducted on the NOX CEMS at
least once every calendar quarter as specified in Part 60,
Appendix F, Procedure 1, Section 5.1.2, except that a CGA is
not required during a quarter when a RATA is being
performed.
§60.107a(c)(5)
Rule 335-3-16-.05(c)
An Annual accuracy determination shall be made for the O2
monitors
§60.107a(c)(5)
Daily calibration drifts shall be made on both the NOX and O2
monitors
§60.107a(c)(5)
The fuel gas system must meet the following requirements:
Shall be equipped with a fuel gas H2S monitor that is installed,
operated, calibrated, and maintained to continuously monitor
and record the concentration by volume (dry basis) of H2S in
the fuel gas before being burned in a process heater or boiler.
§60.107a(a)(2)
§60.13(c)
A Relative Accuracy Test Audit (RATA) shall be conducted on
the H2S monitor at least once every four calendar quarters as
specified in Part 60, Appendix F, Procedure 1 Section 5.1.2
§60.107a(a)(2)(iii)
A Cylinder Gas Audit shall be conducted on the H2S monitor at
least once every calendar quarter as specified in Part 60,
Appendix F, Procedure 1, Section 5.1.2, except that a CGA is
not required during a quarter when a RATA is being
performed.
§60.107a(a)(2)(iii)
BTU heat content testing shall consist of capturing a
representative sample of the fuel gas stream at a frequency of
no less than once each month.
[Fuel Gas Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(1)(ii)
47
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The frequency of analysis may be modified upon receiving
Departmental approval.
Rule 335-3-16-.05(c)(1)(ii)
The following monitoring requirements shall be met to comply with
the WPS for new or reconstructed units designed to burn gas 1 fuels
subcategory under the Boiler MACT:
Each process heater with a heat input capacity greater than or
equal to 10 million Btu per hour (MMBTU/hr) must complete
a tune-up annually as specified in §63.7540(a)(10).
§63.7510(g), §63.7515(d),
§63.7540(a)(10)
Subsequent tune-ups must occur no more than thirteen (13)
months after the previous tune-up.
§63.7515(d)
Each tune-up must be conducted while burning the type of
fuel that provided the majority of the heat input to the unit
over the 12 months prior to the tune-up.
§63.7540(a)(10)
Annual tune-ups do not apply to units with continuous oxygen
trim systems that maintains an optimum air to fuel ratio.
§63.7540(a)(10)
For units with an oxygen trim and less than 5 MMBtu/hr,
burner inspections may be delayed until the next scheduled or
unscheduled unit shutdown; however, you must inspect each
burner at least once every seventy-two (72) months.
§63.7540(a)(12)
If an oxygen trim system is utilized on a unit without emissions
standards to reduce the tune-up frequency to once every five
(5) years, set the oxygen level no lower than the oxygen
concentration measured during the most recent tune-up.
§63.7540(a)(12)
If the unit is not operating on the required date for a tune-up,
the tune-up must be conducted within 30 calendar days of
startup.
§63.7540(a)(13)
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (l) of this
section of this subpart shall be maintained and made available for
inspection. These records may be in electronic format provided they
are readily accessible.
The date, starting time and duration of each deviation from
the requirements specified in this subpart along with the
cause and corrective actions taken.
Rule 335-3-16-.05(c)(2)
§60.107a(i)(1)(ii), (3),(4)
§63.7560
48
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
The date, time, and results of each performance tests along
with any other tests conducted on the boiler or process heater
that provides additional stack pollutant content data.
Rule 335-3-16-.05(c)(2)
Date and type of process heater maintenance that affects air
emissions
Rule 335-3-16-.05(c)(2)
Fuel gas BTU heat content
[Heat Content (BTU/scf)]
Rule 335-3-16-.05(c)(2)
Fuel gas H2S content
[H2S Content (Mole %)]
Rule 335-3-16-.05(c)(2)
§60.102a(g)(1)(ii)
Fuel gas consumption per unit
[Volume (Mscf/Month)]
Rule 335-3-16-.05(c)(2)
§60.13, §60.48c(g)(2)
§60.107a(a) & (b)
where, the fuel gas consumption rate shall be recorded by a
continuous monitor on each unit
MMBTU of fuel gas consumption per unit: Rule 335-3-16-.05(c)(2)
Unit Fuel Gas Heat Input (MMBTU/Month) =
[ Volume (Mscf/Month)] X [ Heat Content (BTU/scf) ]
{1,000}
A running total of hours per calendar year when a fuel other
than natural gas or other gas-1 fuel is burned in a process
heater and/or boiler
§63.7555(h)
Operating hours per unit
[Unit Hours (Hours/Month)]
Rule 335-3-16-.05(c)(2)
Monthly VOC emissions shall be determined for each process
heater or combined stack, as follows:
Rule 335-3-16-.05(c)(2) &
Rule 335-3-14-.04
[BACT & Anti-PSD Limits]
Unit Emissions (Lbs/Month) =
[Unit Heat Input (MMBTU/Month)] X [Test EF (Lbs/MMBTU)]
where, test emission factors (EF) (Lbs/MMBTU) shall be taken
from the most recent performance test
49
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Unit Emissions (Lbs/Hour) =
[ Unit Emissions (Lbs/Month) ]
[ Unit Hours ( Hours/Month) ]
A copy of the NOX CEMS monitoring record for process heaters
shall be maintained onsite in a form suitable for inspection.
Rule 335-3-16-.05(c)(2)
§60.107a(c)(1)-(5)
A record of each visible emission observation conducted on a
unit, when required.
Rule 335-3-16-.05(c)(2)
To demonstrate compliance with NSPS Ja, the following recordkeeping
and reporting requirements shall be met:
§60.108a(a)
§60.7
An excess emissions report and/or summary report shall be
submitted semi-annually on the following reporting schedule:
Rule 335-3-16-.05(c)(2)
§60.7(c), (d), §60.19(d), (e)
Reporting Period Submittal Date
January 1 - June 30 August 28
July 1 - December 31 February 28
The excess emission report shall include the following: §60.107a
Each rolling 3-hr period and each rolling 365-day
period during which the average H2S concentration in
the fuel gas (measured using the continuous H2S
monitor) exceeds its allowable.
§60.107a(i)(1)(ii)
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
Discharges greater than 500 Lb SO2 in excess of the
allowable limits shall be recorded as specified in
§60.108a(c)(6) no later than 45 days following the end
of the discharge exceeding the threshold
§60.108a(c)(6)
Each rolling 30-day period during which the average
concentration of NOX (measured by the NOX CEMS)
exceeds its allowable.
§60.107a(i)(3)
Rule 335-3-14-.04(9)(b)
[PSD/BACT Limit]
The information specified in §60.7(c) and the applicable
requirement in §60.108a(d) shall be provided in each excess
emissions report.
§60.7(c)
§60.108a(d)
To demonstrate compliance with the Boiler MACT, the following
requirements shall be met:
The following notifications shall be submitted: §63.7545
50
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
Notifications specified in §63.7545(a) §63.7545(a)
Notification of alternative fuel usage during periods of
natural gas curtailment or supply interruption shall be
submitted within forty-eight (48) hours of the
declaration of such period
§63.7545(f)
The following records shall be maintained: §63.7555
A copy of each notification and report to comply with
this subpart according to §63.10(b)(2)(xiv)
§63.7555(a)(1)
Records of compliance demonstrations as required by
§63.10(b)(2)(vii)
§63.7555(a)(2)
If an alternative fuel is used in the boilers or process
heaters during periods of gas curtailment or gas
supply emergencies, the following records shall be
maintained:
§63.7555(h)
(i) Record of the total hours per calendar year
that the alternative fuel is burned
(ii) Record of the total hours per calendar year
that the unit operated during periods of gas
curtailment or gas supply emergencies.
A record of burner inspection shall be maintained for
units with delayed tune-ups
§63.7550(c)(5)(xiv)
Records must be kept and maintained as specified in §63.7560
for a period of five years following each occurrence.
§63.7560
The following reporting requirements shall be met: §63.7550
An annual compliance report shall be submitted as
specified in §63.7550(b)(1) through (3), except as
allowed in §63.7550(b)(4)
§63.7550(b), §63.10(a)(7)
The compliance report must contain the information
specified in §63.7550(c)(1.
§63.7550(c)(1)
The reports must be submitted electronically to the
EPA via CEDRI, except as allowed and a copy of the
report must be submitted to the Department for
tracking purposes
§63.7550(h)(3)
51
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
A periodic monitoring report (PMR) meeting the requirements
specified in proviso 4(a) and (b) of this section of this subpart shall be
submitted to the Department.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups and shutdowns.
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the
permit that can be used to determine or indicate
compliance, that identifies an affected source has
failed to meet an applicable emission limit or
standard, or that a work practice was not complied
with or completed.
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
Except as provided for in proviso 4(c) of this section, the report
shall include the information specified in proviso 4(b)(1) of this
section of this subpart.
For each deviation event, the following information
shall be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
52
Provisos for Post-Black Warrior Expansion Units: Process Heaters & Boilers
Federally Enforceable Provisos Regulations
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period
and shall be submitted according to the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 4(b) of this section may
be modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the general proviso subpart
of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
53
Summary Page for Emergency Engines
Permitted Operating Schedule/Unit:
Emergency Operating Schedule: Unlimited [§60.4211(f)(1)]
Maintenance and Testing Operating Schedule: 100 hours/yr-Non-Emergency Hours per year
[§60.4211(f)(2)]
Non-Emergency Operating Schedule: < 50 Hours per year [§60.4211(f)(3)]
Emission Limitations:
EMISSION
POINT
DESCRIPTION POLLUTANT EMISSION
LIMIT *
REGULATIONS
40 CFR 60 SUBPART IIII [NSPS IIII] COMPRESSION IGNITION EMERGENCY FIRE PUMP ENGINES ≥ 500 BHP:
UE-P-100A
UE-P-100B
700 BHP, Generac, C18 ACERT
Diesel- Fired Emergency Fire
Pump Engine No. 1
700 BHP Generac, C18 ACERT
Diesel- Fired Emergency Fire
Pump Engine No. 2
PM
NOX + NMHC
CO
0.23 Lb/hr [0.15 g/HP-
hr]
4.63 Lb/hr [3.0 g/HP-hr]
4.01 Lb/hr [2.6 g/HP-hr]
§60.4205(c), Table 4
§60.4205(c), Table 4
Rule 335-3-14-.04
[Anti-PSD Limit]
§60.4205(c), Table 4
40 CFR 60 SUBPART IIII [NSPS IIII] COMPRESSION IGNITION EMERGENCY ENGINE ≥ 500 BHP:
US-ME-3249X 762 BHP, Generac, SD/MD 500,
Diesel Fired, South Complex
Flare Area Emergency Electric
Generator Engine
PM
NOX + NMHC
CO
0.15 g/HP-hr
4.78 g/HP-hr
2.61 g/HP-hr
§60.4201(a)
§60.4204(b)
§89.112(a), Table 1
§60.4202(a)(2)
§60.4205(b)
§89.112(a), Table 1
§60.4201(a)
§60.4204(b)
§89.112(a), Table 1
EACH EMERGENCY ENGINE LISTED ABOVE Opacity During these specified
periods:
20% during acceleration
mode
15% during lugging
mode
50% during peak periods
§60.4201(a)
§60.4204(b)
[NSPS IIII]
§89.113(a)(1)
§89.113(a)(2)
§89.113(a)(3)
54
EMISSION
POINT
DESCRIPTION POLLUTANT EMISSION
LIMIT *
REGULATIONS
Opacity During all other periods:
No more than one 6 min
avg> 20%
OR
No 6 min avg. > 40% in
any sixty (60) minute
period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
Sulfur Burn non-road diesel fuel:
Maximum sulfur content
of 15 parts per million
(ppm) per gallon
AND
Must meet a cetane index
of at least 40
OR
Maximum aromatic content
of 35 volume percent
§60.4207(b)
§80.510(b)(1)(i)
§80.510(b)(2)(i)
§80.510(b)(2)(ii)
*Limits are for each engine listed
55
Permitted Operating Schedule/Unit:
Emergency Operating Schedule Unlimited [40 CFR §60.4243(d)(1)]
Maintenance and Testing Operating Schedule: 100 hours/yr-Non-Emergency Hours per year
[40 CFR §60.4243(d)(2)]
Non-Emergency Operating Schedule: < 50 Hours per year [40 CFR §60.4243(d)(3)]
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT REGULATIONS
40 CFR 60 Subpart JJJJ [NSPS JJJJ] SPARK IGNITION EMERGENCY ENGINES ≤ 500 BHP:
US-ME-3249 402 BHP BHP , Generac SG300,
Four stroke rich burn (4SRB),
Natural Gas-Fired Backup
Emergency Electrical Generator
Engine w/catalytic converter
NOX
CO
VOC
1.77 Lb/hr [2.0 g/HP-hr]
3.54 Lb/hr [4.0 g/HP-hr]
0.89 Lb/hr [1.0 g/HP-hr]
§60.4233(e), Table 1
Rule 335-3-14-.04
[Anti-PSD Limit]
SC-OPS-SG150 230.3 BHP, Generac SG150, 4SRB,
Natural Gas-Fired, OPS Shelter
emergency generator engine
NOX
CO
VOC
2.0 g/HP-hr
4.0 g/HP-hr
1.0 g/HP-hr
§60.4233(e), Table 1
EACH EMERGENCY ENGINE LISTED ABOVE Opacity No more than one 6 min
avg> 20%
OR
No 6 min avg. > 40% in any
sixty (60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
56
Permitted Operating Schedule/Unit:
Emergency Operating Schedule Unlimited [40 CFR §63.6640(f)(1)]
Maintenance and Testing Operating Schedule: 100 hours/yr-Non-Emergency Hours per year
[§63.6640(f)(2)]
Non-Emergency Operating Schedule: < 50 Hours per year [40 CFR §63.6640(f)(2), (f)(3)]
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT* REGULATIONS
EXISTING MACT ZZZZ ENGINES, MAJOR HAPS ≤ 500 BHP:
00439
00680
10317
20214
00649
136 BHP Diesel-Fired Emergency No. 2
Fire Pump Engine
110.7 BHP Natural Gas-Fired Main
Office Emergency Electrical Generator
Engine
80 BHP Diesel Fired CU Emergency
Stormwater Pump Engine
80 BHP Diesel Fired CK Emergency
Stormwater Pump Engine
20 BHP Liquefied Petroleum Gas (LPG)-
Fired Guard House Emergency Electrical
Generator Engine
HAPs Applicable Work Practices:
Change Oil and Filter every 500
hrs or annually, whichever
comes first or according to
§63.6625(i)
Check Air Cleaner [CI] OR Spark
Plugs [SI] every 1,000 hrs or
annually, whichever comes
first
Check Belts & Hoses every 500
hrs or annually, whichever
comes first
§63.6602, Table 2(c)
§63.6625(i)
EACH ENGINE LISTED ABOVE Opacity No more than one 6 min avg>
20%
OR
No 6 min avg. > 40% in any
sixty (60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
*Work Practice and Opacity Standards are for each engine listed
57
Permitted Operating Schedule/Unit:
24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT REGULATIONS
EXISTING MACT ZZZZ ENGINE, MAJOR HAPS >500 BHP:
00445 525 BHP Diesel-Fired No. 4
Emergency Fire Pump
Engine
NOX
CO
VOC
NONE Exempt from requirements
under MACT ZZZZ
[§63.6590(b)(3)(iii]
Opacity No more than one 6 min avg>
20%
OR
No 6 min avg. > 40% in any
sixty (60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
58
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
Applicability
Each emergency engine, except the UE-P-100A and B engines, is
subject to the applicable requirements of ADEM Admin. Code r.
335-3-4-.01, “Visible Emissions” for Control of Particulate
Emissions and to the requirements of this subpart of this permit.
Rule 335-3-4-.01(1)(a) and (b)
Engine Nos.: US-E-P-100A, US-E-P-100B, and US-ME-3249., are
subject to an emission limits limit in order to avoid a review
under ADEM Admin. Code r. 335-3-14-.04, “Air Permits
Authorizing Construction in Clean Areas [Prevention of Significant
Deterioration (PSD)]”, and they are subject to the requirements
specified in this subpart of this permit. Compliance with emission
limits under 40 CFR 60 Subpart IIII, demonstrate compliance with
the subpart.
Rule 335-3-14-.04
[Anti-PSD Limit]
Each emergency engine on the summary page of this subpart
shall be subject to the requirements specified in ADEM Admin.
Code r. 335-3-16-.03, “Major Source Operating Permits”, and the
requirements specified in this subpart of this permit.
Rule 335-3-16-.03
The following engines are subject to the requirements of 40 CFR
60 Subpart IIII, “Standards of Performance for Compression
Ignition (CI) Internal Combustion Engines” [NSPS IIII] and to the
requirements of this subpart of this permit: Engine Nos. US-E-P-
100A, US-E-P-100B, and US-ME-3249X.
§60.4200(a)(2)(i) [Non-Fire Pump]
§60.4200(a)(2)(ii) [Fire Pump]
§60.4200(a)(4), §60.4208
§63.6590(b)(1)(i)
The following engines are subject to the requirements of 40 CFR
60, Subpart JJJJ, “Standards of Performance for Stationary Spark
Ignition Internal Combustion Engines” [NSPS JJJJ] and to the
requirements of this subpart of this permit: Engine Nos. US-ME-
3249 and SC-OPS-SG150.
§60.4230(a)(4)(iv)
§63.6590(c)(6)
The following engines are subject to the major source
requirements of 40 CFR 63 Subpart ZZZZ, “National Emission
Standards for Hazardous Air Pollutants (HAPs) for Stationary
Reciprocating Internal Combustion Engines (RICE)” [MACT ZZZZ,
RICE MACT] and to the requirements of this subpart of this
permit: Engine Nos. 00439, 00680, 10317, 20214, and 00649.
§63.6580
§63.6585(a),(b)
§63.6590(a)(1)(ii), (b)(1)(i),(b)(3)(iii)
§63.6645(f)
The following engines are subject only to the limited
requirements under this subpart as specified in
§63.6645(f): Engine Nos. US-E-P-100A, US-E-P-100B, and
US-ME-3249X.
§63.6590(b)(1)(i)
59
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
The SC-OPS-SG150 engine satisfies the requirements of
MACT ZZZZ by complying with NSPS JJJJ. No further
requirements apply under this subpart.
§63.6590(c)(6)
Engine No. 00445 is exempt from the requirements of
this subpart provided that it meets the requirements
specified in §63.6590(b)(3)(iii).
§63.6590(b)(3)(iii)
Each engine is subject to the applicable requirements of 40 CFR
60, Subpart A “General Provisions”, and 40 CFR 63 Subpart A,
“General Provisions” as specified in the applicable subparts and
to the requirements of this subpart of this permit.
§60.4218, Table 8, NSPS IIII
§60.4246, Table 3, NSPS JJJJ
§63.6665, Table 8, RICE MACT
§63.6590(b)(3)
Emission Standards
The emergency engines must comply with the following opacity
standards and/or smoke emission standards
For each engine, the following opacity standards
specified below shall be met
The engine shall not discharge into the
atmosphere particulate that results in an opacity
greater than 20%, as determined by a 6-minute
average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-
minute period, the engine shall not discharge
into the atmosphere particulate that results in
an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
For Engine Nos.: US-P-100A and B and US-ME-3249X, the
following smoke emission standards specified in §89.113
shall be met during the specified periods found below
and during all other periods the requirements specified
in proviso 1(a) of this section of the permit shall be met:
§60.4211(a)(3)
§89.113(a)
Acceleration mode, opacity shall not exceed 20
percent (%)
§89.113(a)(1)
Lugging mode, opacity shall not exceed 15% §89.113(a)(2)
Peaks in either the acceleration or lugging
modes, opacity shall not exceed 50 %
§89.113(a)(3)
60
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
To comply with the requirements of NSPS IIII and Anti-PSD Limits
(where applicable), the following emissions standards shall be
adhered to over the entire life of each certified engine
§60.4205(c), §60.4206
Table 4
§60.4211(c)
For emergency fire pump engines UE-P-100A and B,
Particulate Matter (PM) emissions for each
engine shall not exceed 0.23 pounds per hour
(Lb/hr) [0.15 grams per horsepower hour (g/HP-
hr)].
§60.4205(c), Table 4
Nitrogen Oxide (NOx) + Non-Methane
Hydrocarbon (NHMC or Volatile Organic
Compounds (VOC)) emissions for each engine
shall not exceed 4.63 Lb/hr [3.0 g/HP-hr].
§60.4205(c), Table 4
Rule 335-3-14-.04
[Anti-PSD Limit]
Carbon Monoxide (CO) emissions for each
engine shall not exceed 4.01 Lb/hr [2.6 g/HP-hr].
§60.4205(c), Table 4
For emergency generator engine US-ME-3249X, §60.4202(a)(2), §60.4205(b)
PM emissions shall not exceed 0.15 g/HP-hr. §60.4201(a), §60.4204(b)
[NSPS IIII]
§89.112(a), Table 1
NOX + NMHC emissions shall not exceed 4.78
g/HP-hr.
§60.4202(a)(2), §60.4205(b)
[NSPS IIII]
§89.112(a), Table 1
CO emissions shall not exceed 2.61 g/HP-hr. §60.4201(a), §60.4204(b)
[NSPS IIII]
§89.112(a), Table 1
If an emergency engine does not meet the non-
emergency engine standards, the engine shall be
equipped with a non-resettable hour meter prior to
startup of the engine.
§60.4209(a)
If a special fuel, not certified to meet the applicable
standard is used in an engine, the requirements specified
in §60.4217 shall be met.
§60.4217
Except as allowed under §60.4207(b), fuel gas for the
emergency engines shall meet the following per-gallon
gas requirements:
§60.4207(b), §80.510(b)
Maximum sulfur content of 15 ppm §80.510(b)(1)
61
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
Minimum cetane index of 40 or maximum
aromatic content of 35 volume percent
§80.510(b)(2)(i) or (ii)
To comply with the requirements of NSPS JJJJ and Anti-PSD Limits
(where applicable), the following emissions standards shall be
met:
Engine No. US-ME-3249 shall adhere to the following
requirements:
NOX emissions shall not exceed 1.77 Lb/hr [2.0
g/HP-hr].
§60.4233(e), Table 1
Carbon Monoxide (CO) emissions shall not
exceed 3.54 Lb/hr [4.0 g/HP-hr].
§60.4233(e), Table 1
VOC emissions shall not exceed 0.89 Lb/hr [1.0
g/HP-hr].
§60.4233(e), Table 1
Shall be equipped with a catalytic converter Rule 335-3-14-.04
[Anti-PSD Limit]
Engine No. SC-OPS-SG150 shall adhere to the following
emission limitations the entire life of the engine:
§60.4233(e), Table 1
(1) NOX emissions shall not exceed 2.0 g/HP-hr.
(2) CO emissions shall not exceed 4.0 g/HP-hr.
(3) VOC emissions shall not exceed 1.0 g/HP-hr.
Each engine is certified, and it must adhere to the
requirements specified in §60.4243(a)(1) or (2).
§60.4243(a) and (b)(1)
Each engine may operate using propane for a maximum
of 100 hours per year as an alternative fuel solely during
emergency operations.
§60.4243(e)
To comply with the requirements of MACT ZZZZ, the following
work practice standards shall be adhered to for Engine Nos.:
00439, 00680, 10317, 20214, and 00649 as specified in Table No.
2c, Item Nos. 1 (for compression ignition diesel-fired engines)
and No. 6 (for spark ignition natural gas-fired engines):
§63.6602, Table No. 2c
§63.6605(b), Table No. 6
The oil and oil filter shall be changed according one of the
following schedules:
62
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
(1) Every 500 hours of operation, or annually,
whichever comes first,
(2) According to the Oil Analysis Program outlined in
§63.6625(i)
Inspect the following component every 1000 hours of
operation, or annually, whichever comes first.
(1) For a Compression Ignition Source, check the Air
Cleaner
(2) For a Spark Ignition Source, check the spark plugs
Inspect all hoses and belts every 500 hours of operation,
or annually, whichever comes first. Hoses and belts shall
be replaced as necessary.
The management practices specified in provisos 4(a)
through (c), may be delayed if the unit is operating during
an emergency situation, or if the required management
practices would result in an unacceptable risk. In this
case, the required management practice(s) shall be
conducted as soon as possible.
Each unit shall be operated and maintained in a manner
consistent with safety and good air pollution control
practices for minimizing emissions.
Except as otherwise specified, each emergency engine subject to
requirements under this subpart of this permit shall adhere to
the following operating schedules:
For emergency situations, there is no limit on the use of
the engine.
§60.4211(f)(1) [NSPS IIII]
§60.4243(d)(1)[NSPS JJJJ]
§63.6640(f)(1) [MACT ZZZZ]
Any operation other than emergency operations,
maintenance and testing, emergency demand response,
and operation in non-emergency situation for 50 hours
per year is prohibited.
§60.4211(f) [NSPS IIII]
§60.4243(d) [NSPS JJJJ]
§63.6640(f) [MACT ZZZZ]
For any combination of purposes specified in proviso
5(c)(1) through (3) of this section, each emergency
engine may be operated for a maximum of 100 hours per
calendar year. Any operation for non-emergency
situations as allowed by proviso 5 (d) of this section
§60.4211(f)(2) [NSPS IIII]
§60.4243(d)(2) [NSPS JJJJ]
§63.6640(f)(2),(3) [MACT ZZZZ]
63
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
counts as part of the 100 hours per calendar year
allowed.
(1) Maintenance checks and readiness testing
(2) Emergency demand response
(3) Periods where there is a deviation of voltage or
frequency of five (5) percent or greater below
standard voltage or frequency.
For non-emergency situations, each engine may operate
for up to 50 hours per calendar year. Additionally, for a
generator engine these 50 hours shall not be used for
peak shaving, non-emergency demand response, or
income generation.
§60.4211(f)(3) [NSPS IIII]
§60.4243(d)(3) [NSPS JJJJ]
§63.6640(f)(3) [MACT ZZZZ]
Where applicable, the start-up, idling, and loading period
of the engine shall not exceed 30 minutes.
§63.6625(h)
If emergency engines do not operate in accordance with
the requirement listed in the subpart, the engine will not
be considered an emergency engine and it must comply
with non-emergency engine requirements.
§60.4211(f) [NSPS IIII]
§60.4243(d) [NSPS JJJJ]
§63.6640(f) [MACT ZZZZ]
These requirements do not apply to Engine No.: 00445 §63.6590(b)(3)(iii)
Each engine shall only burn fuel that meets the appropriate
specifications for either natural gas, liquefied petroleum gas
(LPG), or diesel, except as allowed.
Rule 335-3-14-.04 [Anti-PSD]
§60.4207(b), §60.4243(e)
§80.510(b)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards shall be determined using
Method 9 or Method 22 of 40 CFR 60 Appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
The following requirements must be adhered to when
performance testing is required:
Rule 335-3-1-.05
Rule 335-3-16-.05(c)(1)(i)
§60.4212, §60.4244
A test shall consist of three runs of at least 1-hour in
duration.
Each run shall test for the applicable pollutants NOX, CO,
and VOC using the reference methods and procedures
specified in NSPS IIII and/or NSPS JJJJ if required.
64
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
(1) For NOX emissions, 40 CFR 60 Appendix A,
Method 7 OR 7A OR 7B OR 7C OR 7D OR 7E
(2) For CO emissions, 40 CFR 60 Appendix A, Method
10 OR Method 10A OR Method 10B
(3) For VOC emissions, 40 CFR 60 Appendix A,
Method 18 OR Method 25 OR Method 25A, OR
Method 25B OR Method 25D OR Method 25E
Particulate emissions shall be measured using 40 CFR 60
Appendix A, Method 5.
The pollutants tested for and the methods and
procedures that are utilized may be modified upon
receiving Departmental approval.
Emission Monitoring
Provided that visible emissions, in excess of the opacity
standards, are observed from an engine at any time that the unit
is operating, a visible emission observation shall be conducted
utilizing one the specified methods.
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
If an emergency engine does not meet the standards applicable
to non-emergency engines, a non-resettable hour meter shall be
installed on each engine.
§60.4209(a), §60.4214(b)
§60.4237
§63.6625(f)
The catalytic converter installed on Engine No. US-ME-3249 must
meet the following requirements:
Rule 335-3-14-.04
[Anti-PSD Limit]
§60.4243g
Must be maintained and operated in a manner so as to
minimize the emissions of regulated air pollutants
Shall not be operated without the entire gas stream
passing through the catalytic converter
Air-to-fuel ratio controllers must be maintained and
operated appropriately in order to ensure proper
operation of the engine and control device to minimize
emissions at all times
65
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
For engines subject to the requirements of NSPS IIII (Engine Nos.:
UE-P-100A, UE-P-100B, and US-ME-3249X) or NSPS JJJJ (Engine
No.: SG-OPS-SG150 and US-ME-3249), compliance with the
applicable emissions standards shall be determined by meeting
one of the following monitoring requirements:
Operate and maintain the unit according to
manufacturer’s specifications for the life of the unit.
For NSPS IIII Engines:
§60.4206, §60.4211(a)
For NSPS JJJJ Engines:
§60.4248, §60.4243(a)(1), (b)(1), (d)
Perform emissions testing every three years or 8,760
hours of operation, whichever comes first
For NSPS IIII Engines:
§60.4211(g)(3), §60.4212,
§60.4213
For NSPS JJJJ Engines:
§60.4243(a)(2), (b)(2),
§60.4244, §60.4245(d) and (e)
For engines subject to the requirements of MACT ZZZZ (Engine
Nos.: 00439, 00680, 10317, 20217, and 00649), one of the
following operations and maintenance plans outlined in Table
No. 6, No. 9 shall be complied with:
Rule 335-3-16-.05(c)(1)
§63.6640(a)
§63.6625(e)(3)
Operate and maintain the stationary engine according to
the manufacturer’s emission-related operation and
maintenance instructions
The facility may develop and follow its own maintenance
plan, provided this plan ensures, to the extent
practicable, the operation and maintenance of the unit
in a manner consistent with good air pollution practices.
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (i)
of this section of this subpart shall be maintained and made
available in a form suitable for inspection for a period of five (5)
years or as specified in the applicable subpart of §60.7(f) or
§63.10(b):
Rule 335-3-16-.05(c)(2)
§60.7(f), §63.10(b)
The date, starting time and duration of each deviation
from the requirements specified in this subpart along
with the cause and corrective actions taken.
§63.6655(a)(1)
§63.6660(a) & (b)
66
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
The date, starting time and, and duration of each
malfunction, along with steps taken to minimize
emissions, and corrective actions taken.
Rule 335-3-16-.05(c)(2)
§63.6655(a)(2) & (5)
§63.6660(a) & (b)
Date and type of engine maintenance that affects air
emissions
Rule 335-3-16-.05(c)(2)
§60.4214(a)(2)(ii) §60.4245(a)(2)
§63.6655(a)(4), (d), & (e)(2)
§63.6660(a) & (b)
A copy of the manufacturer’s certification OR other proof
that the unit is meeting the required emission limits.
For Diesel Engines:
§60.4214(a)(2)(iii) & (iv)
For Natural Gas Engines:
§60.4245(a)(3) & (4)
A copy of the fuel gas certification shall be maintained
onsite.
Rule 335-3-16-.05(c)(2)
§63.6660(a) & (b)
Operating hours for each engine’s usage type:
[ Operating Hours/Month]
Rule 335-3-14-.04
[Anti-PSD Limit]
Rule 335-3-16-.05(c)(2)
§60.4214(b), §60.4245(b)
§63.6655(f)
§63.6660(a) & (b)
If an emergency engine operates for more than 15 hours
per calendar year for the purposes specified in NSPS IIII
or NSPS JJJJ, an annual report shall be submitted:
§60.4214(d)
§60.4245 (e)
(1) The report must contain the information
specified in the applicable subpart
§60.4214(d)(1)
§60.4245 (e)(1)
(2) The report must be submitted on the schedule
specified in the applicable subpart
§60.4214(d)(2)
§60.4245 (e)(2)
(3) Except as allowed, the annual report must be
submitted electronically using the subpart
specific reporting form in the Compliance and
Emissions Data Reporting Interface (CEDRI) that
is accessed through EPA's Central Data Exchange
(CDX) (www.epa.gov/cdx). A notification of the
annual report’s submittal to EPA must be
provided to the Department.
§60.4214(d)(3)
§60.4245 (e)(3)
If an engine is subject to NSPS JJJJ, the following
recordkeeping requirement shall be met:
67
Provisos for Emergency Engines
Federally Enforceable Provisos Regulations
The records specified in §60.4245(a) shall be
maintained.
§60.4245(a)
For engines that do not meet the standards
applicable for non-emergency engines, the
requirements specified in §60.4245(b) shall be
maintained.
§60.4245(b)
Provided that propane is used for a maximum of
100 hours per year as an alternative fuel during
emergency operation, a record of such use shall
be maintained.
§60.4243(e)
Records of each occurrence when a visible emission
observation was conducted on an engine shall be
maintained
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
These records may be kept in electronic form, provided
that they are readily accessible. Alternatively, they may
be kept in hardcopy form.
Rule 335-3-16-.05(c)(2)
§63.6660(a), (b), & (c)
If performance testing is required a copy of the test much be
submitted to the Department within 60 days after the test has
been completed.
§60.4245(d)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner
that complies with proviso 15(b) and 21(b) of the General Permit
Provisos subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
§63.6640(b)
§63.6650(f)
68
[THIS PAGE LEFT BLANK INTENTIONALLY]
69
Summary Page for NSPS QQQ: Oily Wastewater System
Permitted Operating Schedule: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT REGULATIONS
Each aggregate facility that receives,
treats or processes oily wastewater,
comprising:
Individual drain system
Downstream sewer lines
Downstream oil-water separators
VOC
OHAPs
Work Practices:
Install & Maintain Seals
NONE*
Classified as Group 2
wastewater stream under
MACT CC
§60.692-2
Rule 335-3-6-.08(5)
§63.647
AGGREGATE FACILITIES FOR:
Diesel Hydrotreater
Crude Unit Pumping Station
Gasoline Loading Rack
Hydrocracker
CCR Platformer
No. 2 Hydrogen Plant
No. 2 Amine System
No. 2 Wastewater Plant
70
Provisos for Oily Wastewater System
Federally Enforceable Provisos Regulations
Applicability
Each affected facility that is identified on the Summary page of this subpart
shall be subject to the requirements of ADEM Admin. Code r. 335-3-16,
“Major Source Operating Permits”, and to this subpart of this permit.
Rule 335-3-16-.03
Each aggregated facility is subject to the requirements of 40 CFR 60 subpart
QQQ “Standards of Performance for VOC Emissions from Petroleum
Refinery Wastewater Systems” [NSPS QQQ] and the requirements
specified in this subpart of this permit.
§60.690(a)(1), (4), (b)
Compliance with this subpart shall demonstrate compliance with
ADEM Admin. Code r. 335-3-6-.08(5), “Petroleum Refinery
Sources” for any wastewater (oil/water) separator at a petroleum
refinery.
Rule 335-3-6-.08(5)
335-3-10-.01(2)
The wastewater stream has been designated as a Group 2 stream
under “National Emission Standard for Hazardous Air Pollutants
(HAPs) from Petroleum Refineries” [Refinery MACT 1/MACT CC];
therefore, there are no requirements for Group 2 wastewater
streams unless the requirement in §63.640(o)(2) of MACT CC are
met.
§63.640(o)(2)
§63.641
Compliance with the applicable requirements of 40 CFR 60 subpart
A, “General Provisions” shall be met as specified in NSPS QQQ.
40 CFR 60 Subpart A
Emission Standards
Except as specified in §60.692-1(d) and §60.692-2(d), each individual drain
system shall meet the following requirements at all times, except during
periods of start-ups, shutdowns, and malfunctions:
§60.692-1(a), (d)
§60.692-2(d)
§60.692-4
Each drain shall be equipped with a water seal. §60.692-1(a), §60.692-2(a)(1)
§60.692-4
Each junction box shall be equipped with a cover that is tightly
sealed around the edges. The junction box may have a vent pipe
that is at least 90 cm [~3 ft] long, with a diameter of not more than
10.2 cm [~4 in].
§60.692-1(a)
§60.692-2(b)(1), (2)
§60.692-4
Each sewer line shall not be open to atmosphere and shall be
covered or enclosed in a manner so as to have no visual gaps or
cracks in joints, seals, or other emission interfaces.
§60.692-1(a)
§60.692-2(c)(1)
§60.693-1(e)(1)
§60.692-4
71
Provisos for Oily Wastewater System
Federally Enforceable Provisos Regulations
As an alternative to the standards found in §60.692-2 for individual
drain systems, the drain system may be constructed such that it is
completely enclosed and equipped with a closed vent system that
meets the standards in §60.692-5.
§60.692-1
§60.692-2
§60.692-4
§60.693-1
An alternative means of emission limitation to meet the requirements of
§§60.692-2 through 60.692-4 may be granted as provided in §60.694.
§60.692-1(c)
§60.692-2-§60.692-4
§60.692-4
Compliance and Performance Test Methods and Procedures
The test methods and procedures specified in section §60.696 of 40 CFR
Part 60, Subpart QQQ shall be followed.
§60.696
Emission Monitoring
Each individual drain system shall be visually or physically inspected
according to the following frequencies:
Each drain in active service shall be visually inspected initially, and
monthly thereafter for indications of low water levels, or other
conditions that would reduce the effectiveness of the water seal
controls.
§60.692-2(a)(2)
Each drain not in active service shall be visually inspected:
(1) Initially, and weekly thereafter for indications of low water
levels, or other problems that could result in VOC
emissions.
§60.692-2(a)(3)
OR
(2) Initially, and semi-annually thereafter to ensure that a
tightly sealed caps and/or plugs is in place and properly
installed.
§60.692-2(a)(4)
Each junction box shall be visually inspected initially, and semi-
annually thereafter to ensure that the cover is in place and tightly
sealed around the edges.
§60.692-2(b)(3)
Each unburied sewer system shall be visually inspected initially,
and semi-annually thereafter to check for cracks, gaps, or other
problems that could result in VOC emissions.
§60.692-2(c)(2)
§60.693-1(e)(2)
The following requirements shall apply to problems discovered during
visual and/or physical inspections of the individual drain system:
72
Provisos for Oily Wastewater System
Federally Enforceable Provisos Regulations
In the event that a drain seal or plug is missing, and/or the drain
water level is low, water shall be added or first efforts at repair
shall be made as soon as practicable, but not later than 24 hours
after detection, except as provided in §60.692-6.
§60.692-2(a)(5)
§60.692-6.
In the event that a junction box cover is missing or seal is cracked,
or a gap or crack is discovered in an unburied sewer line, a first
attempt at repairs/replacements shall be attempted as soon as
practicable, but not later than 15 days after discovery.
§60.692-2(b)(4)
§60.692-2(c)(3)
§60.693-1(e)(3)
In the event that emissions are detected from a closed vent
system, a first attempt at repairs/replacements shall be attempted
as soon as possible, but no later than 30 days after discovery.
§60.693-1(b)
§60.692-5(e)
As an alternative to provisos 2(a) through (c) of this section, repairs
may be delayed if it is technically impossible to complete the
repairs without shutting down all or part of the facility or process
unit. Repairs shall be completed by the end of the next facility or
process unit shutdown.
§60.692-6
If the alternative standards of individual drain systems found in §60.693-1
are elected, the monitoring requirements specified in §60.695 for a closed
vent system shall be met as applicable.
§60-692-5,
§60.693-1(b)
§60.695
Recordkeeping and Reporting Requirements
The recordkeeping requirements specified in proviso 1(a) through (f) of this
section shall be complied with.
The location, date, and corrective action taken for each problem
uncovered during inspections of drains, junction boxes, sewer
lines, and closed vent systems.
§60.692-1(b),
§§60.697(a), (b), (d)
For a closed vent system complying with the standards found in
60.692-5 and closed drain systems complying with the alternative
standards specified in §60.693-1, the records specified in
§60.697(d) shall be maintained.
§60.692-5
§60.693-1
§60.697(d)
For systems placed on the Delay of Repair (DOR) list, as allowed by
§60.692-6, a written document signed by the owner or operator
(or designee) explaining the reason(s) for the delay, the expected
date of repair, and the actual date of repair shall be retained
onsite.
§60.692-1(b)
§§60.697(a), (e)
73
Provisos for Oily Wastewater System
Federally Enforceable Provisos Regulations
A copy of the design specification as described in §60.697(f) for all
equipment used to comply with the proviso of this subpart shall be
maintained for the life of the source in a readily accessible location.
§60.697(f)
A copy of the information specified in §§60.697(g) through (k) shall
be maintained.
§§60.697(g)-(k)
The records specified in §60.7 of 40 CFR Part 60, Subpart A shall be
maintained.
§60.7
Periodic monitoring reports (PMR) meeting the requirements specified in
proviso 2(a) and 2(b) of this section of this subpart shall be submitted to
the Department.
Rule 335-3-16-.05(c)(3)(i)
§60.7
§60.19
§60.698
Each report shall identify each incidence of deviation from a permit
term or condition including those that occur during startups,
shutdowns, and malfunctions.
(1) A deviation shall mean any condition determined by
observation, by data collected by any continuous
monitoring system or periodic monitoring required by the
permit that can be used to determine compliance, that
identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
(2) If no deviation event occurred during reporting period, a
statement that indicates there were no deviations from
the permit requirement requirements shall be included in
the report.
Except as provided for in proviso 2(c) of this section, the report
shall include the information specified in proviso 2(b)(1) of this
section of this subpart.
(1) For each deviation event, the following information shall
be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
74
Provisos for Oily Wastewater System
Federally Enforceable Provisos Regulations
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period and
shall be submitted according to the following reporting
schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 2(b) of this section may be
modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
75
Summary Page for MACT CC and BWON NESHAP: Wastewater Stream
Containing HAPs
Permitted Operating Schedule: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission limitations:
Emission
Point Description Pollutant
Emission
Limit/Standard Regulations
Wastewater streams and treatment
operation contacting or containing
hazardous air pollutants
OHAP
Operate in a manner
consistent with the minimum
or maximum (as appropriate)
permitted concentration or
operating parameter value.
§63.640(c)(3), §63.647
40 CFR 63, Subpart CC
For TAB < 10 Mg/yr
For TAB >10 Mg/yr
Benzene
Benzene
Work Practices-Calculate and
Record TAB
Work Practices—Install
controls to reduce benzene
emissions
§61.342(a)
[NESHAP FF]
§61.342(c)-(d)
[NESHAP FF]
76
Provisos for Wastewater Stream Containing HAPs
Federally Enforceable Provisos Regulations
Applicability
Each wastewater stream and treatment operation shall be subject to the
requirements specified in ADEM Admin. Code r. 335-3-16, “Major Source
Operating Permits”, and to this subpart of this permit.
Rule 335-3-16-.03
Except as provided for in §63.640(d) and (g) of 40 CFR Part 63 Subpart CC
“National Emission Standard for Hazardous Air Pollutants (HAPs) from
Petroleum Refineries” [Refinery MACT 1/MACT CC], each wastewater
stream and treatment operation that meets the following criteria shall be
subject to MACT CC and to this subpart of this permit.
§63.640(c)(3)
§63640(d) & (g)
§63.647(a)
Is located at a petroleum refinery site that is a major HAP emission
source.
§63.640(a)(1)
§63.641
§61.340(a)
Emits or has equipment containing or contacting one or more of
the hazardous air pollutants as defined in Table No. 1 of MACT CC.
§63.640(a)(2)
Table No. 1
Is a Group 1 wastewater steam as defined in §63.641 and as
follows:
§63.641
§63.647(a)
Has a total annual benzene (TAB) loading of 10 megagrams
(Mg) per year (~22,046 pounds per year) or greater.
Has a flow rate of 0.02 liters (0.00258 gallons) per minute
or greater
Has a benzene concentration equal to or greater than 10
parts per million by weight (ppmw)
Is not exempt from the control requirements under the
provisions of 40 CFR Part 61, Subpart FF
A Group 1 or Group 2 wastewater stream that is conveyed, stored,
or treated in a wastewater steam management unit that also
receives stream subject to §63.133 through §63.147 of 40 CFR 63
Subpart G, “National Emission Standards for Organic Hazardous
Air Pollutants from the Synthetic Organic Chemical Manufacturing
Industry for Process Vents, Storage Vessels, Transfer Operations,
and Wastewater” for wastewater provisos shall comply with
requirements specified in §63.640(o)(2) to comply with MACT CC.
§63.640(o)(2)
Compliance with MACT CC shall be met by complying with the
applicable requirements by reference found in 40 CFR Part 61,
Subpart FF “National Emission Standards for Benzene Waste
Operations” [BWON] for hazardous waste treatment, storage, and
§61.340(a), (b)
§63.647(a)
77
Provisos for Wastewater Stream Containing HAPs
Federally Enforceable Provisos Regulations
disposal facilities that treat, store, or dispose of hazardous waste
generated by petroleum refineries.
Each wastewater stream and treatment operation shall be subject to the
applicable requirements specified in Table 6 of MACT CC, 40 CFR 63
Subpart A, “General Provisions”, and this subpart of this permit.
§63.642(c)
Table 6, 40 CFR 63, Subpart CC
Emission Standards
If the total annual benzene (TAB) quantity from facility waste is less than
10 Mg/yr (11 tons/year), it is exempt from the requirements of §61.342(b)
and (c) of the BWON. The TAB waste quantity shall be determined as
specified in §61.342(a) of the BWON on an annual basis.
§61.342 (a)
If the total annual benzene (TAB) quantity from facility waste is greater
than or equal to 10 Mg/yr (11 tons/year) as determined by §61.342(a) of
the BWON, the facility waste shall comply with the requirement of
§61.342(c) through (h) of the BWON.
§61.342 (b)
§61.342(c)-(h)
A Group 1 wastewater stream shall comply with the requirements of
§61.340 through §61.355 of the BWON for a process wastewater stream
that meets the definition in §63.641.
§61.340
§61.355
§63.641
§63.647(a)
All terms not defined in §63.641 of MACT CC shall have the
meaning provided in §63.641 of the BWON.
§63.647(b)
If a flare is used as a control device, the flare shall meet the
requirements of §63.670 of MACT CC.
§63.647(c)
Operate in a manner consistent with the minimum or maximum
(as appropriate) permitted concentration or operating parameter
values, if required under the BWON to perform periodic
measurement of benzene concentration in wastewater, or to
monitor process or control device operating parameters.
§63.647(d)
Operation of the process, treatment unit, or control device
resulting in a measured concentration or operating parameter
value outside the permitted limits shall constitute a violation of the
emission standards
§63.647(d)
Failure to perform required leak monitoring for closed vent
systems and control devices or failure to repair leaks within the
time period specified in the BWON shall constitute a violation of
the standard.
§63.647(d)
78
Provisos for Wastewater Stream Containing HAPs
Federally Enforceable Provisos Regulations
A Group 2 wastewater stream does not meet the definition of a Group 1
wastewater stream as defined in §63.641.
§63.641
The following exemptions shall apply for Group 1 wastewater streams:
Waste streams identified in §61.340(c) of the BWON and
§63.640(d)(1) of MACT CC are exempt from the requirements of
those subpart.
§61.340(c)
§63.640(d)(1)
Any gaseous stream from a waste management unit, treatment
process, or wastewater treatment system routed to a fuel gas
system, as defined in §61.341, is exempt from the BWON.
§61.340(d)
No testing, monitoring, recordkeeping, or reporting is required
under this subpart for any gaseous stream from a waste
management unit, treatment process, or wastewater treatment
unit routed to a fuel gas system
§61.340(d)
Compliance and Performance Test Methods and Procedures
Compliance with the BWON shall be determined by review of facility
records and results from tests and inspection using the methods and
procedures specified in §61.355 of the BWON.
§61.342(g)
§61.355
Emission Monitoring
Monitoring of operations that are subject to proviso 2 and 3 of the emission
standards section of this subpart, shall be conducted as specified in
§61.354 to ensure that the unit is properly operated and maintained by the
appropriate monitoring procedures.
§61.354
Recordkeeping and Reporting Requirements
The following recordkeeping and reporting requirements shall be met to
demonstrate compliance with the wastewater provisions specified in
§63.647:
§63.647
§63.655(a)
Unless the requirements of §63.640(o)(2)(ii) of MACT CC are being
met, the recordkeeping requirements specified in §61.356 of the
BWON and the reporting requirements specified in §61.357 of the
BWON shall be complied with.
§61.356
§61.357
§63.640(o)(2)(ii)
§63.655(a)
There are no additional reporting and recordkeeping requirements
for wastewater under MACT CC unless a wastewater stream is
included in an emissions average.
§63.655(a)
79
Provisos for Wastewater Stream Containing HAPs
Federally Enforceable Provisos Regulations
Recordkeeping and reporting for emissions averages are specified
in §63.653 and in §63.655(f)(5) and (g)(8) of MACT CC.
§63.653
§63.655(a)
§63.655(f)(5)
§63.655(g)(8)
Each record shall be maintained in a readily accessible location at
the facility site for a period not less than two years from the date
the information is recorded unless otherwise specified.
§61.356
A periodic monitoring report (PMR) meeting the requirements specified in
proviso 2(a) and (b) of this section of this subpart shall be submitted to the
Department.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a permit
term or condition including those that occur during startups and
shutdowns.
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the permit
that can be used to determine or indicate compliance, that
identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If no deviation event occurred during the reporting period,
a statement that indicates there were no deviations from
the permit requirements shall be included in the report.
Except as provided for in proviso 2(c) of this section, the report
shall include the information specified in proviso 2(b)(1) and (2) of
this section of this subpart.
(1) For each deviation event, the following information shall
be submitted:
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
80
Provisos for Wastewater Stream Containing HAPs
Federally Enforceable Provisos Regulations
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
A copy of emissions test performed per MACT CC, or a
statement referencing those tests, shall be included with
each monitoring report.
Each report shall cover a calendar semi-annual period and
shall be submitted according to the following reporting
schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 2(b) of this section may be
modified upon receipt of Departmental approval.
A copy of the Total Annual Benzene [TAB] calculation covering a calendar
12-month period shall be submitted to the Department annually within 60
days of the end of the calendar annual reporting period.
Rule 335-3-16-.05(c)(3)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
81
SUMMARY PAGE FOR NSPS VVa & MON: DI-METHYL SULFIDE (DMS) UNIT
Permitted Operating Schedule: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT REGULATIONS
INDIVIDUAL SOURCES PART OF THE DMS UNIT:
STORAGE TANKS:
T-300 Methanol Storage Tank
w/Internal Floating Roof
Methanol Complying with
NSPS Kb
§63.2535(c)
[MON/MACT FFFF]
PROCESS VENTS:
None No vent meets the
definitions in §63.2550 of
the MON
TRANSFER RACKS:
Transfer Racks are classified
as Group 2
OHAP None*
*Classified as a Group 2 Rack
§63.2475
[MON/MACT FFFF]
WASTEWATER STREAMS:
DMS Produced water
stream & Maintenance
water stream
Methanol Work practices
Recordkeeping & Reporting
per 40 CFR 63 Subpart G
§63.2485
[MON/MACT FFFF]
FUGITIVE VOC & OHAP EMITTING EQUIPMENT
Valves, flanges, pumps,
piping, etc.
OHAP
VOC
LDAR Program
LDAR Program
§63.2480
[NESHAP UU]
§60.482-1a
[NSPS VVa]
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Applicability
Each affected facility that is identified on the Summary Page of this subpart
shall be subject to the requirements of ADEM Admin. Code r. 335-3-16,
“Major Source Operating Permits”, and to this subpart of this permit.
Rule 335-3-16-.03
Each piece of equipment in organic hazardous air pollutant (OHAP) service
(including wastewater, piping, and ancillary equipment) that is listed on the
summary page is subject to the requirements of 40 CFR 63 Subpart FFFF ,
“National Emission Standards for Hazardous Air Pollutants: Miscellaneous
Organic Chemical Manufacturing“ [MON/NESHAP FFFF], and the
requirements in this subpart of this permit
§63.2430, MON
§63.2435, MON
§63.2440(a), (b), (c)(1) , MON
§63.2445, MON
§63.2450, MON
§63.2550, MON
Compliance with the applicable requirements of 40 CFR 63 subpart
A, “General Provisions” [Subpart A], shall be met as specified in
Table No. 12 of the MON.
§63.2540, MON
Table 12, MON
Nothing in this section shall preclude the Permittee from selecting
another compliance option allowed by this subpart, provided
written notice is first supplied to the Department.
§63.2480, MON
§63.2485, MON
Each piece of equipment in VOC service listed on the summary page is
subject to the requirements of 40 CFR 60 Subpart VVa, “Standards of
Performance for Equipment Leaks of VOC in the Synthetic Organic Chemicals
Manufacturing Industry” [NSPS VVa], and the requirements in this subpart
of this permit
§60.480a, NSPS VVa
§60.481a, NSPS VVa
Emission Standards
Except as specified in §63.2485(b) through (o) of the MON and during
periods of start-ups, shutdowns, or malfunctions, the wastewater stream
off of the DMS unit shall meet the following requirements:
§63.2450(a) , MON
§63.2455(a, MON)
§63.2485(a) , MON
Table 7, No. 2, MON
(a) A maintenance wastewater stream containing methanol, which is
listed as an organic HAP in Table 9 of the MON, shall meet the
maintenance wastewater requirements specified in §63.105 of 40
CFR 63, Subpart F, “National Emission Standards for Organic
Hazardous Air Pollutants From the Synthetic Organic Chemical
Manufacturing Industry" [NESHAP F], and the requirements in this
subpart of this permit, except as specified in §63.2485 of the MON.
§63.2450(a), MON
Table 7, No. 2, MON
§63.2485(a) & (b)
§63.105, NESHAP F
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(1) As specified in §63.105(b) of the MON, a description of
maintenance procedures for management of wastewaters
generated from the emptying and purging of equipment in
the process during temporary shutdowns for maintenance-
turnaround and during routine maintenance shall be
prepared
§63.105(b), MON
(i) This document shall be kept current and modified
as needed to reflect operational procedures.
§63.105(c), MON
(ii) Procedures from this document shall be
incorporated into the start-up, shutdown, and
malfunction plan.
§63.105(d), MON
A record of the information required in the maintenance
procedure description shall be retained onsite as part of the
start-up, shutdown, and malfunction plan.
§63.105(e), MON
A process wastewater stream containing methanol, which is listed
as an organic HAP in Table 9 of the MON, shall comply with the
applicable requirements specified in 40 CFR 63, Subpart G,
“National Emission Standards for Organic HAP from the Synthetic
Organic Chemical Manufacturing Industry for Process Vents,
Storage Vessels, Transfer Operations, and Wastewater” [NESHAP
G], and the requirements in this subpart of this permit, except as
specified in §63.2485 of the MON.
§63.2450(a), MON
Table 7, No. 2, MON
§63.2485(a) & (b), MON
(1) The wastewater stream classification [Group 1 or Group 2]
will be determined using the following criteria initially and
whenever a process change is made that could affect the
status:
63.2450(a) , MON
Table No. 7, No. 1, MON
§63.2485(a), (b), & (c), MON
§63.132(a)(1)(i), (b)(1)(i),
(b)(2)(i), & (c), NESHAP G
(i) A wastewater stream will be designated as Group 1
if one (or more) of the following is met:
(A) The total annual average concentration of
compounds listed in Table No. 8 of the MON
is ≥ 10,000 ppmv AND the total annual load
of compounds listed in Table No. 8 of the
MON is ≥ 200 Lb/yr
OR
(B) The total annual average concentration of
compounds listed in Table No. 8 of the MON
is ≥ 1,000 ppmv AND the annual average
flowrate is ≥ 1 L/min
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OR
(C) The combined total annual average
concentration of compounds listed in Table
Nos. 8 & 9 of the MON is ≥ 30,000 ppmv
AND the combined total annual load of
compounds listed in Table Nos. 8 & 9 of the
MON is ≥ 1 Ton/yr
(ii) Any stream not designated as Group 1 will be
designated as Group 2.
A Group 1 Stream shall meet the emission standards in
§63.133, §63.134, §63.135, §63.136, §63.137, and §63.138
of NESHAP G, except as modified by §63.2485(d), (e), (f), (g),
(m), and (n) of the MON.
§63.2450(a), MON
Table No. 7, No. 1, MON
§63.2485(a), (b), & (c), MON
§63.132(a)(2) & (b)(3),
NESHAP G
A Group 2 Stream shall only be subject to the applicable
recordkeeping and reporting requirements specified in
§63.146(b)(1) and §63.147(b)(8) of NESHAP G.
§63.2450(a), MON
Table No. 7 , No. 1, MON
§63.2485(a), (b), & (c), MON
§63.132(a)(3) & (b)(4) NESHAP G
Each piece of equipment shall comply with the applicable equipment leak
requirements specified in §63.1021 through §63.1037 of 40 CFR Part 63
Subpart UU, “National Emission Standards For Equipment Leaks—Control
Level 2 Standards”, [NESHAP UU], except as modified by §63.2480(b) of the
MON. Additionally, all equipment shall be subject to §§60.482-1a through
§60.484a of NSPS VVa.
§63.2480(a), MON
Table No. 6, No. 1(a) and 2(a)(i),
MON
§63.2450(a), MON
§60.480a, NSPS VVa
Opening of a safety device shall be allowed at any time that it is required to
avoid unsafe operating conditions.
§63.2450(p), MON
If the emissions from different emission sources subject to this subpart of
this permit are combined and are sent to a single control device, the
requirements specified in §63.2450(c) of the MON shall be met.
§63.2450(c), MON
Each affected source, including air pollution control and monitoring
equipment, shall always be operated and maintained in accordance with the
requirements specified in proviso §63.6(e)(1)(i) of Subpart A.
§63.2450(a), MON
The following requirement shall be met for control devices subject to the
MON:
(a) Provided a non-flare control device is being utilized, a monitoring
plan shall be submitted that meets the control device requirements
specified in proviso §63.2450(e) of the MON.
§63.2450(e), MON
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(b) A flare used as a control device shall meet the flare compliance
requirements in §63.2450(f) of the MON.
§63.2450(f), MON
A written startup, shutdown, and malfunction plan shall be developed and
implemented in accordance with the requirements specified in proviso
§63.6(e)(3) of Subpart A.
§63.2450(a), MON
Table 12, MON
Each affected source shall be operated in accordance with §63.6(e)(1) and
(3) of Subpart A during each startup, shutdown, or malfunction.
§63.2450(a), MON
Table 12, MON
Compliance and Performance Test Methods and Procedures
Each wastewater stream shall be sampled according to the methods
specified in §63.143, §63.144, and §63.145 of NESHAP G, except as modified
by §63.2485(h), (j), and (k) of the MON.
§63.2485(a), MON
Evaluations on flares shall be conducted when necessary according to
§63.2450(f) of the MON.
§63.2450(f), MON
Performance tests on non-flare control devices shall be conducted when
necessary according to §63.2450(g), (h), and (i) of the MON.
§63.2450(g), MON
Leaks shall be determined according to the methods and procedures
specified in §63.1023 of NESHAP UU AND §60.485a (d)-(f) of NSPS VVa.
Rule 335-3-16-.05(c)(1)(i),
§60.480a(e)(2)(i), NSPS VVa
§63.1023, NESHAP UU
Emission Monitoring
The following monitoring systems requirements shall be met to
demonstrate compliance with the MON:
(a) A Continuous Emissions Monitoring System (CEMS) OR Continuous
Parameter Monitoring System [CPMS] shall be installed, operated,
and maintained on each control device.
§63.2450(j) & (k), MON
A CEMS shall meet the requirements of §63.2450(j) of the
MON
CPMS shall meet the requirements of §63.2450(k) of the
MON
The requirements for performance tests as specified in 63.2450(g)
of the MON shall be complied with where applicable for control
devices.
§63.2450(g), MON
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For equipment leaks, the following monitoring requirements shall be met:
Inspections and monitoring shall meet the applicable requirements
and frequency specified in §§63.1021 through §63.1037 of NESHAP
UU, except as modified by §63.2480(b) of the MON.
§63.2480(a), MON
Table No. 6, No. 1(a) OR No.
2(a)(i), MON
§63.2450(a), MON
All equipment leaks shall comply with the monitoring requirements
in §60.482-1a through §60.484a of NSPS VVa.
§60.480a, NSPS VVa
The annual average concentration and annual average flowrate shall be
determined for each wastewater stream associated with the DMS Unit. The
procedures for flexible operating units specified in §63.144 (b) and (c) of
NESHAP G do not apply for the purposes of the MON.
§63.2485(j), MON
Recordkeeping and Reporting Requirements
A copy of the following records shall be maintained onsite for a period of
five (5) years:
§63.10(b), Subpart A
A description of all operating scenarios as specified in §63.2525(b)
of the MON shall be kept.
§63.2525(b), MON
For the wastewater streams:
For all Group 1 streams, as applicable, records of all of the
items required by §63.147 of NESHAP G shall be
maintained.
§63.2525(a), MON
§63.147, NESHAP G
For all Group 2 streams, records of only the items in
§63.147(b)(8)(i) through (iv) of NESHAP G shall be
maintained.
§63.2525(a), MON
§63.147(b)(8), NESHAP G
Records required by §63.1038 of NESHAP UU and §60.486a of NSPS
VVa shall be maintained.
§63.2525(a), MON
§60.486a
Records of all control devices and closed vent systems, in use §63.2525(a), MON
A record of each time a safety device is opened to avoid an unsafe
condition in accordance with §63.2450(s) of the MON.
§63.2525(f), MON
A record of each CEMS OR CPMS check, maintenance, and date,
time, and duration of each downtime.
§63.2485(o), MON
§63.2525(g) & (h), MON
The date, time, and duration of each start-up, shutdown, and
malfunction, along with the corrective actions taken.
§63.2525(h), MON
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The following reporting requirements shall be met:
(a) A Compliance Report shall include the applicable information
specified in §63.2520(e)(1) through (10) of the MON.
§63.2450(m), MON
§63.2520(e)(1)-(10), MON
Table 11, No. 3, MON
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or testing
or recordkeeping which is required by the permit that can
be used to determine or indicate compliance, that identifies
an affected source has failed to meet an applicable
emission limit or standard, or that a work practice was not
complied with or completed.
If there are no deviations events that occurred during the
reporting period, a statement that indicates there were no
deviations from the permit requirements shall be included
in the report.
Each report shall be submitted semi-annually on the following
reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1 - December 31 February 28
§§63.2520(a), (b)(5)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
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89
Summary Page for NSPS K: Petroleum Liquid Storage Vessels
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
All petroleum liquid storage vessels with a capacity > 40,000 gallons and constructed, reconstructed, or modified after June 11, 1973, but before May 19, 1978
Maximum True Vapor Pressure (TVP)
1.5 psia < TVP < 11.1 psia
TVP > 11.1 psia
VOC Work Practice Standards
Install floating roof or vapor recovery system or equivalent system
Install vapor recovery system or equivalent system
§60.112(a)(1) [NSPS K] §60.112(a)(2) [NSPS K]
STORAGE VESSELS:
WITH EXTERNAL FLOATING ROOF:
T-088
T-089
1,614,350 gallons [Subject to NSPS K & Group 2 MACT CC| Comply NSPS K]
1,614,350 gallons [Subject to NSPS K & Group 2 MACT CC| Comply NSPS K]
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Provisos for NSPS K Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Applicability
Each storage vessel that is identified in the Summary Page of this
subpart shall be subject to the requirements specified in ADEM Admin.
Code r. 335-3-16, “Major Source Operating Permits”, and in this
subpart of this permit.
Rule 335-3-16-.03
Except as provided for in §60.110(b) of 40 CFR Part 60, Subpart K
“Standards of Performance for Storage Vessels from Petroleum
Liquids” [NSPS K], each storage vessel that is identified in the Summary
Page of this subpart shall comply with the requirements of NSPS K and
the requirements specified in this subpart of this permit.
Rule 335-3-10-.02(9)
§60.110(a) and (b)
If overlap of 40 CFR Part 63 Subpart CC “National Emission
Standard for Hazardous Air Pollutants from Petroleum
Refineries” [Refinery MACT 1/MACT CC], with NSPS K occurs
after the compliance dates specified in §63.640(h) of MACT CC
the following requirements shall be met:
§63.640(h)
Each Group 2 storage vessel subject to NSPS K and
MACT CC, but not subject to the control requirements
under NSPS K, must comply only with the
requirements specified under MACT CC.
§63.640(n)(7)
§63.641
Each Group 2 storage vessel that is subject to the
control requirements under NSPS K, must comply only
with the requirements specified under NSPS K.
§63.640(n)(6)
§63.641
The applicable requirements specified under 40 CFR Part 60,
Subpart A, “General Provisions”, shall be complied with.
40 CFR 60 Subpart A
Emission Standards
Provided that the true vapor pressure of the petroleum liquid, as
stored, is greater than or equal to 1.5 psia but less than or equal to 11.1
psia, the storage vessel shall be equipped with one of the following:
§60.112(a)(1)
A floating roof
A vapor recovery system
An equivalent system
Provided that the true vapor pressure of the petroleum liquid, as
stored, is greater than 11.1 psia, the storage vessel shall be equipped
with one of the following:
§60.112(a)(2)
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Provisos for NSPS K Petroleum Liquid Storage Vessels
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A vapor recovery system
An equivalent system
Compliance and Performance Test Methods and Procedures
There are no testing requirements for NSPS K tanks.
Emission Monitoring
Periodic monitoring shall be in the form of maintaining records as
specified in the recordkeeping and reporting requirements section of
this subpart.
Rule 335-3-16-.05(c)(1)(ii)
Recordkeeping and Reporting Requirements
Except as provided for in §60.113(d) of NSPS K, the following
recordkeeping and reporting requirements specified in §60.113 of
NSPS K shall be maintained on a monthly basis, made available for
inspection and submitted to the Department when requested:
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
§60.113(a), (b), (c), and (d)
§60.7(a) and (b)
§60.19
Record of the petroleum liquid stored
Record of the period of storage
Record of the maximum true vapor pressure of the liquid
during the respective storage period as specified in §60.113(b)
and (c) of NSPS K
A monthly record of the information specified in provisos 2(a) through
(c) of this section of this subpart shall be maintained for each storage
vessel.
Rule 335-3-16-.05(c)(2)
Contents of each tank
ThrougHPut of each tank
Average storage temperature of each tank
A periodic monitoring report (PMR) meeting the requirements
specified in proviso 3(a) and (b) of this section of this subpart shall be
submitted to the Department.
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups and shutdowns.
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Provisos for NSPS K Petroleum Liquid Storage Vessels
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A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the
permit that can be used to determine or indicate
compliance, that identifies an affected source has
failed to meet an applicable emission limit or standard,
or that a work practice was not complied with or
completed.
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
Except as provided for in proviso 3(c) of this section, the report
shall include the information specified in proviso 3(b)(1) of this
section of this subpart.
For each deviation event, the following information
shall be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
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Provisos for NSPS K Petroleum Liquid Storage Vessels
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Each report shall cover a calendar semi-annual period
and shall be submitted according to the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 3(b) of this section may
be modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the general proviso subpart
of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
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95
Summary Page for NSPS Ka: Petroleum Liquid Storage Vessels
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
All petroleum liquid storage vessels with a capacity > 40,000
gallons and constructed, reconstructed, or modified after
May 18, 1978, but before July 23, 1984
Maximum True Vapor Pressure (TV)
1.5 psia < TVP < 11.1 psia
TVP > 11.1 psia
VOC
Work Practice Standards:
Install floating roof or vapor
recovery system and vapor
return or disposal system to
reduce emissions to atmosphere
by at least 95% by weight or
equivalent system
Install vapor recovery system
and a vapor return or disposal
system to reduce emissions to
atmosphere by at least 95% by
weight
§60.112a(a)
[NSPS Ka]
§60.112a(b)
[NSPS Ka]
STORAGE VESSELS WITH INTERNAL FLOATING ROOF
T–094 630,000 gallon [Subject to NSPS Ka & Group 2 MACT CC| Comply w/NSPS Ka]
T-095 630,000 gallon [Subject to NSPS Ka & Group 2 MACT CC| Comply w/NSPS Ka]
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Applicability
Each storage vessel that is identified in the Summary Page of this subpart
shall be subject to the requirements specified in ADEM Admin. Code r.
335-3-16, “Major Source Operating Permits”, and in this subpart of this
permit.
Rule 335-3-16-.03
Except as provided for in §60.110a(b) of 40 CFR Part 60, Subpart Ka
“Standards of Performance for Storage Vessels from Petroleum Liquids”
[NSPS Ka], each storage vessel that is identified in the Summary Page of
this subpart shall comply with the requirements of NSPS Ka and the
requirements specified in this subpart of this permit.
Rule 335-3-10-.02(9)(a)
§60.110a(a) and (b)
If overlap of 40 CFR Part 63 Subpart CC “National Emission
Standard for Hazardous Air Pollutants from Petroleum Refineries”
[Refinery MACT 1/MACT CC] with NSPS Ka occurs, each Group 2
storage vessel under MACT CC that is subject to the control
requirements under NSPS Ka, must comply only with the
requirements specified under NSPS Ka, except as specified in
§63.640(n)(9) of MACT CC.
§63.640(h)
§63.640(n)(6) and (n)(9)
§63.641
The applicable requirements specified under 40 CFR Part 60,
Subpart A, “General Provisions” shall be met only as specified in
§60.110a(c)(2) of NSPS Ka.
§60.110a(c)(2)
Emission Standards
Provided the true vapor pressure of the petroleum liquid, as stored, is
greater than or equal to 1.5 psia but not greater than 11.1 psia, the
storage vessel shall be equipped with one of the following controls:
§60.112a(a)
A fixed roof and an internal floating roof that meets the
requirements specified §60.112a(a)(2) of NSPS Ka and as follows:
§60.112a(a)(2)
Roof shall be equipped with a continuous closure device
between the tank wall and cover edge.
Cover shall be floating (off the leg supports) at all-times
except during initial fill and when the tank is completely
emptied and subsequently refilled.
Emptying and refilling when the cover is resting on the leg
supports shall be continuous and shall be accomplished
as rapidly as possible
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Provisos for NSPS Ka Petroleum Liquid Storage Vessels
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Each opening in the cover, except for automatic bleeder
vents and the rim space vents, is to provide a projection
below the liquid surface.
Each opening in the cover except for automatic bleeder
vents, rim space vents, stub drains and leg sleeves is to be
equipped with a cover, seal, or liquid which is to be
maintained in a closed position at all times except when
the device is in actual use.
Automatic bleeder vents are to be closed at all time when
the cover is floating except when the cover is being
floated off or is being landed on the leg supports.
Rim vents are to be set to open only when the cover is
being floated off the leg supports or at the
manufacturer’s recommended settings.
OR
Other controls specified in §60.112a (a)(1), (3), or (4). Nothing in
this permit shall preclude a source from selecting a different
control allowed under this subpart.
§60.112a(a)(1) , (3), (4)
Provided the true vapor pressure of the petroleum liquid, as stored, is
greater than 11.1 psia, the storage vessel shall be equipped with a vapor
recovery system and a vapor return or disposal system that meets the
requirements specified in §60.112a(b) of NSPS Ka.
§60.112a(b)
As an alternative means of compliance, compliance with 40 CFR part 65,
Subpart C may be elected to satisfy the requirements of §60.112a through
§60.114a of NSPS Ka for storage vessels that store petroleum liquids with
a maximum true vapor pressure (TVP) greater than or equal to 10.3 kPa
(1.5 psia).
§60.110a(c)
§60.112a-§60.114a
40 CFR part 65, Subpart C
Compliance and Performance Test Methods and Procedures
There are no testing requirements for NSPS Ka tanks that are equipped
with a fixed roof and internal floating roof.
NSPS Ka tanks that are equipped with an external floating roof or for
which a vapor recovery and return or disposal system is equipped shall
comply with testing and procedures specified in §60.113a.
§60.113a
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Federally Enforceable Provisos Regulations
Emission Monitoring
Except as specified in §60.115a(d) of NSPS Ka, monitoring as specified in
§60.115a(a) of NSPS Kaa shall be in the form of recordkeeping as specified
in the recordkeeping and reporting section of this subpart of this permit.
§60.115a(a), (d)
Recordkeeping and Reporting Requirements
Except as provided in §60.115a(d) of NSPS Ka, the following records shall
be maintained on a monthly basis for each storage vessel during the
respective storage period:
§60.7(a), (b)
§60.19
§60.115a(d)
Record of the petroleum liquid stored §60.115a(a)
Period of storage §60.115a(a)
Maximum true vapor pressure of the liquid §60.115a(a)
Typical Reid vapor pressure and the maximum expected storage
temperature if used to determine the maximum true vapor
pressure
§60.115a(b)
True vapor pressure of each type of crude oil §60.115a(c)
A periodic monitoring report (PMR) meeting the requirements specified
in proviso 2(a) and (b) of this section of this subpart shall be submitted to
the Department.
Rule 335-3-16-.05(c)(3)(i)
(a) Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups and shutdowns.
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the permit
that can be used to determine or indicate compliance,
that identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
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Provisos for NSPS Ka Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Except as provided for in proviso 2(c) of this section, the report
shall include the information specified in proviso 2(b)(1) of this
section of this subpart.
For each deviation event, the following information shall
be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period and
shall be submitted according to the following reporting
schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 2(b) of this section may be
modified upon receipt of Departmental approval.
100
Provisos for NSPS Ka Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
101
Summary Page for NSPS Kb Petroleum Liquid Storage Vessels
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
All volatile organic liquid petroleum liquid storage vessels
with a capacity > 19,812.9 gallons and constructed,
reconstructed, or modified after July 23, 1984
VOC Work Practice Standards:
DESIGN CAPACITY MAX TVP
19,812 gallons < DC < 39,890 gallons (75m 3 < DC < 151m3)
4.0 psia < Max TVP < 11.1 psia (27.6 kPa < Max TVP < 76.6 kPa)
DC > 39,890 gallons (DC > 151m3)
0.754 psia < Max TVP < 11.1 psia (5.2 kPa < Max TVP < 76.6 kPa)
DC > 19,812 gallons
(DC > 75m3)
Max TVP > 11.1 psia
(Max TVP > 76.6 kPa)
Install floating roof or
Closed Vent System (CVS)
and control device or
equivalent system
Install CVS and control
device or equivalent
system
§60.112b(a)
[NSPS Kb]
§60.112b(b)
[NSPS Kb]
STORAGE VESSELS:
WITH FIXED ROOF AND CVS [§60.112b(a)(3)]:
T-301
T-302
T-303
20,305 gallons
20,305 gallons
232,190 gallons
[Subject to NSPS Kb & Group 2 MACT CC| Comply w/NSPS Kb]
[Subject to NSPS Kb & Group 2 MACT CC| Comply w/NSPS Kb]
[Subject to NSPS Kb & Group 2 MACT CC| Comply w/NSPS Kb]
WITH INTERNAL FLOATING ROOF [§60.112b(a)(1)]: :
T-097
T-199
T-201
T-202
T-300
T-354
840,000 gallons
3,360,000 gallons
3,360,000 gallons
3,360,000 gallons
271,072 gallons
42,000 gallons
[Subject to NSPS Kb & NSPS QQQ| Comply w/NSPS Kb]
[Subject to NSPS Kb & NSPS QQQ| Comply w/NSPS Kb]
[Subject to NSPS Kb & NSPS QQQ| Comply w/NSPS Kb]
[Subject to NSPS Kb & NSPS QQQ| Comply w/NSPS Kb]
[Subject to NSPS Kb & 40 CFR 63 Subpart FFFF [MON] | Comply w/NSPS Kb]
[Subject to NSPS Kb & Group 1 MACT CC | Comply w/NSPS Kb]
102
Provisos for NSPS Kb Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Applicability
Each storage vessel that is identified in the Summary Page of this
subpart shall be subject to the requirements specified in ADEM Admin.
Code r. 335-3-16, “Major Source Operating Permits”, and in this
subpart of this permit.
Rule 335-3-16-.03
Except as provided in §60.110b(b) and (d) of 40 CFR Part 60, Subpart
Kb, “Standards of Performance for Volatile Organic Liquid (VOL)
Storage Vessels” [NSPS Kb], each storage vessel that is identified in the
Summary Page of this subpart is subject to the requirements of NSPS
Kb and this subpart of this permit
Rule 335-3-10-.02(9)(b)
§60.110b(a)
§60.110b(b)
§60.110b(d)
Since there is overlap of 40 CFR Part 63 Subpart CC, “National
Emission Standard for Hazardous Air Pollutants from
Petroleum Refineries” [Refinery MACT 1/MACT CC] with NSPS
Kb after the compliance dates found in §63.640(h) of MACT CC
for storage vessels, each MACT CC Group 1 and Group 2
storage vessels also subject to NSPS Kb, shall comply only with
NSPS Kb, except as specified in §63.640(n)(8) of MACT CC.
§63.640(h)
§63.640(n)(1), (2), (8)
Since there is overlap of 40 CFR Part 63 Subpart FFFF, “National
Emission Standard for Hazardous Air Pollutants: Miscellaneous
Organic Chemical Manufacturing” [NESHAP FFFF] with NSPS
Kb for storage vessels, the requirements specified under NSPS
Kb only shall be met for the T-300 storage vessel.
§63.2535(c)
Compliance with 40 CFR 60 Subpart A, “General Provisions”
shall be met as specified in NSPS Kb.
§60.110b(e)(2)
Emission Standards
Table No. 1:
Storage Tank
Design Capacity (DC)
(Gallons)
Volatile Organic Liquid
Maximum True Vapor Pressure (TVP)
(psia)
19,812 Gallons < DC < 39,890 Gallons & 4 psia < Max TVP <11.1 psia
DC > 39,890 Gallons & 0.75 psia < Max TVP <11.1 psia
§60.112b(a)
Each storage vessel meeting the applicable requirements specified in
Table No. 1 of this section shall comply with NSPS Kb by equipping each
storage vessels with one of the following:
§60.112b(a)
Install, operate, and maintain a fixed roof in combination with
an internal floating roof that meets the requirements specified
section §60.112b(a)(1) of NSPS Kb.
§60.112b(a)(1)
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Federally Enforceable Provisos Regulations
Install, operate, and maintain any other control device, closed
vent system and control device, or an equivalent system as
allowed under §60.112b(a)(2), (3), or (4) of NSPS Kb. Nothing
in this subpart shall preclude a source from complying with
another control allowed under this subpart.
§60.112b(a)(2), (3), (4)
Install, operate, and maintain a system equivalent to those
described in either proviso 1(a) or 1(b) of this section that
meets alternative means of emission limitation specified in
§60.114b of NSPS Kb.
§60.112b(a)(4)
§60.114b
Table No. 2:
Storage Tank
Design Capacity (DC)
(Gallons)
Volatile Organic Liquid
Maximum True Vapor Pressure (TVP)
(psia)
DC > 19,812 Gallons & Max TVP > 11.1 psia
§60.112b(b)
Each storage vessel meeting the requirements specified in Table No. 2
of this section shall comply with NSPS Kb by meeting the requirements
specified in §60.112b(b).
§60.112b(b)
Each storage vessel storing a waste mixture of indeterminate or
variable composition shall comply with the requirements specified in
§60.116b(f) of NSPS Kb.
§60.116b(f)
As an alternative means of compliance, compliance with 40 CFR part
65, Subpart C may be elected to satisfy the requirements of §60.112b
through §60.117b of NSPS Kb for storage vessels that store petroleum
liquids meeting the requirements in §60.110b(e).
§60.110b(e)
§60.112b-§60.117b
Table No. 3:
Storage Tank
Design Capacity (DC)
(Gallons)
Volatile Organic Liquid
Maximum True Vapor Pressure (TVP)
(psia)
19,812 Gallons < DC < 39,890 Gallons & Max TVP <2.176 psia
DC > 39,890 Gallons & Max TVP <0.508 psia
§60.110b(b)
Storage vessels meeting the requirements specified in Table No. 3 of
this section and those specified in §60.110b(d) of NSPS Kb are exempt
from the requirements of this subpart.
§§60.110b(b), (d)
Compliance and Performance Test Methods and Procedures
The test methods and procedures specified in §60.113b(a) of NSPS Kb
shall be utilized after a permanently affixed roof and internal floating
roof has been installed a storage vessel.
§60.113b(a)
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Federally Enforceable Provisos Regulations
Emission Monitoring
Storage vessels equipped with a permanently affixed roof and internal
floating roof shall be monitored as follows:
§60.113b(a)
The internal floating roof, the primary seal, and the secondary
seal (if in service) shall be visually inspected prior to being filled
with a VOL.
§60.113b(a)(1)
The internal floating roof and the primary seal or the
secondary seal (if in service) shall be visually inspected through
manholes and roof hatches on the fixed roof at least once
every 12 months, but at intervals no greater than 10 years if a
liquid-mounted or mechanical shoe primary seal is installed on
the storage vessel.
§60.113b(a)(2)
§60.113b(a)(4)
Repairs shall be made to the storage vessel or the
vessel shall be emptied and removed from service
within 45 day if defects or failures as specified in
§60.113b(a)(2) of NSPS Kb occur.
If a failure detected during inspections cannot be
repaired or emptied within 45 days, a 30-day
extension may be requested as specified in
§60.113b(a)(2) of NSPS Kb.
Storage vessels equipped with a double-seal system shall be
visually inspected as specified in proviso 1(c)(1) or 1(c)(2) of
this section of this subpart:
§60.113b(a)(3)
§60.113b(a)(4)
At least once every five years, but at intervals no
greater than five years, the vessel shall be visually
inspected as specified in §60.113b(a)(4) of NSPS Kb.
OR
As specified in proviso 1(b) of this section of this
subpart.
Each time the storage vessel is emptied and degassed, a visual
inspection must be conducted on the internal floating roof, the
primary seal, the secondary seal, gaskets, slotted membranes,
and sleeve seals (if any).
§60.113b(a)(4)
Inspections shall occur at intervals no greater than 10
years
105
Provisos for NSPS Kb Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Prior to the vessel being refilled, all defects and
failures must be repaired
Recordkeeping and Reporting Requirements
Except as specified in §60.115b(c)(1), storage vessels meeting the
design capacity and maximum TVP requirements in Table 1 of the
emission standards section of this subpart, records and submitted
reports (depending on the control equipment) shall be maintained for
two years.
§60.115b
§60.115b(c)(1)
The following records shall be maintained for storage vessels equipped
with a fixed roof and internal floating roof:
§60.115b(a)
A report describing the control equipment and certifying that
the control equipment meets the requirements of
§60.112b(a)(1) and §60.113b(a)(1) of NSPS Kb shall be
submitted, with the notification required by §60.7(a)(3) of
subpart A, to the Department.
§60.115b(a)(1)
§60.112b(a)(1)
§60.113b(a)(1)
§60.7(a)(3)
A record of each inspection performed as required under
§60.113b(a)(1) through (a)(4) of NSPS Kb shall be maintained
and shall include the following information:
§60.115b(a)(2)
Identify the storage vessel the inspection was
performed on
Contain the date the vessel was inspected
Contain the observed condition of each component of
the control equipment (seals, internal floating roof,
and fittings).
If any failures or defects are detected during a visual inspection
a report shall be submitted to the Department within 30 days
of the inspection and shall include the following information:
§60.115b(a)(3)
Identify the storage vessel
Identify the nature of the defects
Identify the date the storage vessel was emptied or
the nature of and date the repair was made
The dimensions and an analysis showing the capacity of each storage
vessel subject to NSPS Kb shall be maintained and kept readily
accessible for the life of each vessel.
§60.116b(a) and (b)
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Provisos for NSPS Kb Petroleum Liquid Storage Vessels
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Table No. 4:
Storage Tank
Design Capacity (DC)
(Gallons)
Volatile Organic Liquid
Maximum True Vapor Pressure (TVP)
(psia)
19,812 Gallons < DC < 39,890 Gallons & Max TVP > 2.176 psia
DC > 39,890 Gallons & Max TVP > 0.508 psia
§60.116b(c)
Unless a storage vessel meeting the requirements specified in Table
No. 4 stores a waste mixture of indeterminate or variable composition
or it is equipped with a CVS and a control device, the following records
shall be maintained for each vessel for at least two years:
§60.116b(c), (e), (f), (g)
Record of the VOL stored
Period of storage
Maximum true vapor pressure of the liquid
Table No. 5:
Storage Tank
Design Capacity (DC)
(Gallons)
Volatile Organic Liquid
Maximum True Vapor Pressure (TVP)
(psia)
19,812 Gallons < DC < 39,890 Gallons Max TVP normally < 4.0 psia
DC > 39,890 Gallons Max TVP normally < 0.754 psia
§60.116b(d)
Unless a storage vessel meeting the requirements in Table No. 5 is
equipped with a CVS and a control device, the Department shall be
notified within 30 days when the maximum TVP of the liquid exceeds
the respective maximum true vapor pressure values for each volume
range. This record shall be maintained for at least 2 years.
§60.116b(d)
§60.116b(g)
The Department shall be notified prior to the filling or refilling of each
storage vessel that has to be visually inspected as specified in
§60.113b(a)(5) of NSPS Kb.
§60.113b(a)(5)
Periodic Monitoring Reports (PMR) meeting the requirements
specified in proviso 7(a) and 7(b) of this section of this subpart shall be
submitted to the Department.
Rule 335-3-16-.05(c)(3)(i)
(a) Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups, shutdowns, and malfunctions.
107
Provisos for NSPS Kb Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
A deviation shall mean any condition determined by
observation, by data collected by any continuous
monitoring system or periodic monitoring required by
the permit that can be used to determine compliance,
that identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
Except as provided for in proviso 7(c) of this section, the report
shall include the information specified in proviso 7(b)(1) of this
section of this subpart.
For each deviation event, the following information
shall be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
108
Provisos for NSPS Kb Petroleum Liquid Storage Vessels
Federally Enforceable Provisos Regulations
Each report shall cover a calendar semi-annual period
and shall be submitted according to the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 7(b) of this section may
be modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the general proviso subpart
of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
109
Summary Page for MACT CC: Organic HAP Storage Vessels
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
VOLATILE ORGANIC LIQUID STORAGE VESSELS OHAP Closed vent system w/95%
OHAP reduction or Install
floating roof w/seals and
maintain seals
§63.660(a)
[MACT CC]
GROUP 1 STORAGE VESSELS, AS DEFINED IN §63.641:
Equipped w/ Internal Floating Roof (IFR):
T-003
T-004
T-049
T-203
572,381 gallons
572,381 gallons
804,328 gallons
39,145 gallons
Equipped w/ External Floating Roof (EFR):
T-010
T-011
T-017A
T-060
T-061
T-062
T-063
T-064
T-065
T-066
T-067
T-083
514,805 gallons
514,805 gallons
324,575 gallons
783,214 gallons
783,214 gallons
783,214 gallons
783,214 gallons
840,000 gallons
840,000 gallons
1,599,356 gallons
1,599,356 gallons
2,463,420 gallons
110
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
VOLATILE ORGANIC LIQUID STORAGE VESSELS OHAP NONE
*Installed pre-1972
not reconstructed or
modified
§63.660(a)
[MACT CC]
GROUP 2 STORAGE VESSELS, AS DEFINED IN §63.641:
Equipped w/ Vertical Fixed Roof (VFR):
T-008
T-023
T-027
T-028
T-029
T-031
T-032
T-034
T-035
T-036
T-037
T-038
T-039
T-040
T-042
T-044
T-046
T-048
T-052
T-053
T-055
T-056
T-057
T-058
T-059
T-068
T-080
T-081
T-082
T-087
T-093M
T-096
T-102
T-200
T-353
T-374
E-1
E-2
E-3
E-5
E-6
E-7
E-8
E-9
E-11
E-12
E-13
E-14
E-16
E-17
Equipped w/ External Floating Roof (EFR):
T-085
T-086
111
Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
Applicability
Each organic hazardous air pollutant (OHAP) storage vessel shall be subject
to the requirements specified in ADEM Admin. Code r. 335-3-16, “Major
Source Operating Permits”, and the requirements specified in this subpart of
this permit.
Rule 335-3-16-.03
§63.642(a)
The requirements of 40 CFR 63 Subpart A, “General Provisions”, apply only
as specified in 40 CFR 63, Subpart WW, “National Emission Standards for
Storage Vessels (Tanks)-Control Level 2”, and as specified in this subpart of
this permit.
§63.1060
Each OHAP storage vessel shall be subject to the requirements specified in
40 CFR 63 Subpart CC, “National Emission Standards for Hazardous Air
Pollutants (HAPs) from Petroleum Refineries” [Refinery MACT 1/MACT CC],
and the requirements specified in this subpart of this permit.
§63.640 (a), (c)(2), (c)(7),
(e), (h),(n)
A Group 1 Storage Vessel part of an existing source on or after
February 1, 2016 is defined as a storage vessel that meets the
requirements in proviso 3(a) (1) or (2) of this section of the permit:
§63.641
§63.660
Design Capacity
(DC)
Stored-Liquid
Maximum True
Vapor Pressure
(TVP)
Annual Average
HAP Liquid
Concentration
(1) ≥ 151 cubic meter (m3)
(≥ 40,000 gallons)
≥ 5.2kPa
(0.75 psi)
>4% by weight
total organic HAPs
(2) 76 m3 ≥ DC < 151 m3
(20,000 gallons ≥ DC < 40,000 gallons)
≥ 13.1kPa
(1.9 psi)
>4% by weight
total organic HAPs
(b) A Group 1 Storage Vessel part of a new source on or after February
1, 2016 is defined as a storage vessel that meets the requirements in
proviso 3(b) (1) or (2) of this section of the permit:
§63.641
§63.660
Design Capacity
(DC)
Stored-Liquid
Maximum True
Vapor Pressure
(TVP)
Annual Average
HAP Liquid
Concentration
(1) ≥ 151 m3
(≥ 40,000 gallons)
≥ 3.4 kPa
(0.5 psi)
>2% by weight total
organic HAPs
(2) 76 m3 ≥ DC < 151 m3
(20,000 gallons ≥ DC < 40,000 gallons)
≥ 13.1kPa
(1.9 psi)
>2% by weight total
organic HAPs
(c) A Group 2 Storage Vessel part of a new source or an existing source
is any storage vessel that does not meet the definition of a Group 1
Storage Vessel as specified in Proviso 3(a) or (b) of this section.
§63.641
112
Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
(d) Compliance with MACT CC will satisfy the requirements of the
following storage vessels subject to other regulations:
§63.641
§63.640(a), (c)(2), (c)(7),
(e)(1), (e)(2),§63.640(n),
(q), 63.642(c), (i), (j), (k),
(l), §§63.660 (a), (b), (c)
A Group 1 storage vessel that is part of a new source and
subject to 40 CFR 60 Subpart Kb.
§63.640 (n)(2)
A Group 2 storage vessel that is part of a new source and
subject to 40 CFR 60 Subpart Kb, but not required to install
controls.
§63.640 (n)(4)
A Group 1 storage vessel that is subject to 40 CFR 60 Subpart
K and/or Subpart Ka.
§63.640 (n)(5)
A Group 2 storage vessel that is subject to 40 CFR 60 Subpart
K and/or Subpart Ka, but not required to install controls.
§63.640 (n)(7)
Any storage tank also subject to the requirements of ADEM
Admin. Code Rule 335-3-6-.02, 335-3-6-.03, 335-3-6-.04, and
335-3-6-.23.
§63.640(q)
Rule 335-3-11-.01(2)
(e) Group 1 Storage vessels shall comply with the requirements of 40
CFR 63 Subpart WW OR 40 CFR 63 Subpart SS, “National Emission
Standards for Closed Vent Systems, Control Devices, Recovery
Devices and Routing to a Fuel Gas System or a Process”, as
referenced in MACT CC.
§63.660
All terms not defined in §63.641 shall have the meaning
given to them in subpart A, WW, or SS of 40 CFR Subpart 63.
§63.660(a)
The definitions of “Group 1 storage vessel” (paragraph (2))
and “Storage vessel” in §63.641 shall apply in lieu of the
definition of “Storage vessel” in §63.1061.
§63.660(a)
All references specified in §63.660(c)(1) through (6) shall
apply for the purposes of MACT CC.
§63.660(c)
Nothing in this permit will preclude the Permittee from
selecting an alternate method of compliance allowed under
MACT CC according to §63.980 of Subpart SS.
§63.660
§63.980
113
Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
Emission Standards
A Group 1 storage vessel that is part of a new or existing source storing liquid
with a maximum true vapor pressure less than 76.6 kilopascals (11.1 pounds
per square inch) shall comply with the requirements in 40 CFR 63 Subpart
WW according to the requirements specified in §63.660(a) through (i) of
MACT CC and as specified below:
§63.660
The storage vessel must meet one of following control requirements:
Operate and maintain an internal floating roof (IFR) §63.1062(a)(1)
Operate and maintain an external floating roof (EFR) §63.1062(a)(2)
Comply with an equivalent to the requirements of Proviso
1(a)(1) or (2) by complying with an alternative means of
emission limitation as specified in §63.1064.
§63.1062(a)(3)
§63.1064
Provided that a Group 1 storage vessel is equipped with a floating
roof to comply with §63.1062 of WW, the following requirements
shall be met:
§63.1063
For IFR storage vessels, the design requirements for rim seals
shall be met by equipping the storage vessel with one of the
seal configurations specified in §63.1063(a)(1)(i)(A) through
(C), except as specified in §63.1063(a)(1)(i)(D).
§63.1063(a)(1)(i)(A)-(D)
For EFR storage vessels, the design requirements for rim
seals shall be met by equipping the storage vessel with one
of the seal configurations specified in §63.1063(a)(1)(ii)(A) or
(B), except as specified in §63.1063(a)(1)(ii)(C).
§63.1063(a)(1)(ii)(A)-(C)
For IFR and EFR storage vessels, the design requirements for
deck fittings shall be met as follows:
(i) Equip the opening through the deck of the floating
roof with a fitting as specified in §63.1063(a)(2)(i)
through (viii), except as specified in
§63.1063(a)(2)(ix).
§63.1063(a)(2)(i) through
(ix)
(ii) Provided that the requirements specified in Proviso
1(b)(3)(i) are not met as of June 30, 2014, those
requirements do not apply until the next time the
vessel is completely emptied and degassed, or
January 30, 2026, whichever comes first.
§63.660(b)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
(iii) In addition to the options specified in
§63.1063(a)(2)(viii)(A) and (B) and §63.1064, a
flexible enclosure device and either a gasketed or
welded cap at the top of the guidepole may be used
to comply with §63.1063(a)(2)(viii).
§63.660(b)(1)
(iv) Each opening through a floating roof for a ladder
having at least one slotted leg shall be equipped with
one of the configurations specified in §63.660(b)(2).
§63.660(b)(2)
For IFR and EFR storage vessels, the storage vessel must
meet the operational requirements specified in §63.1063(b).
§63.1063(b)
For IFR and EFR storage vessels, conditions causing
inspection failures under §63.1063(d) shall comply with the
repair requirements under §63.1063(e).
§63.1063(e)
For a Group 1 storage vessel that is part of a new or existing source storing
liquid with a maximum true vapor pressure greater than or equal to 76.6
kilopascals (11.1 pounds per square inch) shall comply with the requirements
specified in 40 CFR 63 Subpart SS and as follows:
§63.660
(a) If a flare is used as a control device, the flare shall meet the
requirements of §63.670
§63.660(i)(1)
§63.670
(b) If a closed vent system contains a bypass line that could divert a vent
stream either directly to the atmosphere or to a control device that
does not comply with the requirement of Subpart SS, the bypass line
must comply with the following requirements:
§63.660(i)(2)
Meet the requirements specified in §63.983(a)(3)(i) or (ii) or
§63.660(i)(2)(iii)
Except as specified in §63.660(i)(2)(i) or (ii) for routine
maintenance, use of the bypass at any time to divert a Group
1 storage vessel is an emission standard violation as
specified in §63.660(i)(2)
For an uncontrolled fixed roof storage vessel that commenced construction
on or before June 30, 2014, and that meets the definition of “Group 1 storage
vessel”, paragraph (2), in §63.641 but not the definition of “Group 1 storage
vessel”, paragraph (1), in §63.641, the requirements of §63.982 of Subpart
SS and/or §63.1062 of Subpart WW do not apply until the next time the
storage vessel is completely emptied and degassed, or January 30, 2026,
whichever occurs first.
§63.660(d)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
At all times, the storage vessels must be operated and maintained, including
associated air pollution control equipment and monitoring equipment, in a
manner consistent with safety and good air pollution control practices for
minimizing emissions as specified in §63.642(n).
§63.642(n)
Emission Monitoring
Inspections shall be conducted on Group 1 Storage vessels that are
complying with Subpart WW to comply with MACT CC as follows:
For IFR storage vessels the following requirements shall be met:
Before the initial filling of an IFR storage vessel inspection
shall be conducted as follows:
§63.1063(c)(1)
(i) Visually inspect the floating roof deck, deck fittings,
and rim seals from within the storage vessel.
§63.1063(d)(1)
(ii) The inspection may be performed entirely from the
top side of the floating roof, as long as there is visual
access to all deck components specified in
§63.1063(a).
§63.1063(d)(1)
(iii) Any of the conditions described in §63.1063 (d)(1)(i)
through (d)(1)(v) constitutes inspection failure.
§63.1063(d)(1)(i)-(v)
Subsequent inspections shall be performed by meeting the
requirements specified in Proviso 1(a)(2)(i) and (ii) of this
section of this subpart:
§63.1063(c)(1)
(i) At least once per year conduct tank-top inspections
of the IFR by visually inspecting the floating roof
deck, deck fitting, and rim seal through opening in
the fixed roof,
§63.1063(c)(1)(i)(A), (d)(2)
(A) Any of the conditions described in §63.1063
(d)(1)(i) through (d)(1)(iv) of this section
constitutes inspection failure.
(B) Identification of holes or tears in the rim seal
is required only for the seal that is visible
from the top of the storage vessel.
(ii) Each time the storage vessel is completely emptied
and degassed, or every 10 years, whichever occurs
first, the IFR shall be inspected as specified in Proviso
1(a)(1)(i)-(iii) of this section of this subpart.
§63.1063(c)(1)(i)(B)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
Instead of the inspection frequency specified in Proviso
1(a)(2) above, subsequent inspections for storage vessels
equipped with two rim seals may be performed each time
the storage vessel is completely emptied and degassed, or
every 5 years, whichever occurs first and according to the
requirements specified in Proviso 1(a)(1)(i)-(iii) of this
section of this subpart.
§63.1063(c)(1)(ii)
For EFR storage vessels the following requirements shall be met:
To determine the presence and size of gaps between the rim
seals and the wall of the storage vessel the requirements
specified in proviso 1(b)(1)(i) and (ii) of this section of this
subpart shall be met by conducting seal gap inspections as
specified in §60.1063(d)(3)(i) :
§60.1063(d)(3)(i)
(i) Inspections of the storage vessels primary and
secondary rim seals shall be inspected within 90
days after the initial filling of the storage vessel
§60.1063(c)(2)(i),(d)(3)
(ii) For subsequent testing, the secondary seal of the
EFR shall be inspected at least once every year and
the primary seal of the EFR shall be inspected at least
every 5 years
§60.1063(c)(2)(ii), (d)(3)
(iii) An exceedance of the following gap requirements
shall constitute inspection failure
§60.1063(d)(3)
(A) The ratio of seal gap area to vessel diameter
for the primary seal shall not exceed 212
square centimeters per meter of vessel
diameter (10 square inches per foot of
vessel diameter) and the maximum gap
width shall not exceed 3.81 centimeter (1.5
inches)
§60.1063(d)(3)(ii)
(B) Except when the secondary seal must be
pulled back or removed to inspect the
primary seal, the ratio of seal gap area to
vessel diameter for the secondary seal shall
not exceed 21.2 square centimeters per
meter of vessel diameter (1 square inch per
foot of vessel diameter) and the maximum
gap width shall not exceed 1.27 centimeter
(0.5 inches)
§60.1063(d)(3)(iii)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
Each time the storage vessel is completed emptied and
degassed, or every 10 years, whichever comes first the
requirements specified in Proviso 1(a)(1)(i)-(iii) of this
section of this subpart shall be met.
§60.1063(c)(2)(iii)
Provided that it has been determined that it is unsafe to
perform the floating roof inspections in Proviso 1(b)(1)(i) or
(ii) of this section of this subpart, the requirements specified
in §60.1063(c)(2)(iv) shall be met.
§60.1063(c)(2)(iv)
For storage vessels previously subject to requirements in §63.646, initial
inspection requirements in §63.1063(c)(1) and (c)(2)(i) or in
§63.983(b)(1)(i)(A), as applicable are not required.
§63.660(e)
Failure to perform other inspections and monitoring required shall constitute
a violation of the applicable standard of this subpart.
§63.660(e)
Compliance and Performance Test Methods and Procedures
Seal gap inspections conducted to measure rim seals on EFR storage vessels
for gaps must be performed using the procedures specified in §60.1063
(d)(3)(i).
§60.1063(d)(3)(i)
Good engineering judgment or test results may be used to determine the
stored liquid weight percent total organic HAP for purposes of group
determination.
§63.660(a)(1)
If the Department and the facility do not agree on whether the annual
average weight percent organic HAP in the stored liquid is above or below 4
percent for a storage vessel at an existing source or above or below 2 percent
for a storage vessel at a new source, an appropriate method (based on the
type of liquid stored) as published by EPA or a consensus-based standards
organization shall be used.
§63.660(a)(2)
Recordkeeping and Reporting Requirements
The recordkeeping requirements shall be met for storage vessels as follows: §63.642(e), §63.655(i)
§63.655(i)(1)(v) and (vi)
Applicable records specified in §63.1065 of Subpart WW found
below or §63.998 of Subpart SS shall be maintained for Group 1
storage vessels.
§63.655(i)(1)(v)
§63.998
§63.1065
Records of the vessel dimension and capacity as specified in
§63.1065(a)
§63.1065(a)
Records of inspection results as specified in §63.1065(b) §63.1065(b)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
Records of floating roof landing as specified in §63.1065(c) §63.1065(c)
Documentation of extensions used in accordance with
§63.1065(e)(2) or §63.1065(c)(2)(iv)(B)
§63.1065(d)
Records specified in §63.1065(a) of Subpart WW shall be maintained
for Group 2 storage vessels. If a storage vessel is determined to be
Group 2 because the weight percent total organic HAP of the stored
liquid is less than or equal to 4 percent for existing sources or 2
percent for new sources, a record of any data, assumptions, and
procedures used to make this determination shall be retained.
§63.655(i)(1)(vi)
§63.660(a)(1)
Copies of all applicable reports and records shall be kept for at least
5 years except as otherwise specified in §63.655(i).
§63.655(i)
§63.1065
All applicable records shall be maintained in such a manner that they
can be readily accessed within 24 hours.
§63.655(i)
§63.1065
Records may be maintained in hard copy or computer-readable form
including, but not limited to, on paper, microfilm, computer, flash
drive, floppy disk, magnetic tape, or microfiche.
§63.655(i)
§63.1065
References in §63.1066(a) to initial startup notification requirements do not
apply.
§63.660(f)
A Notification of Compliance Status (NOCS) Report shall be submitted and
shall include the information specified in §63.655(f)(1)(i) and
§63.655(h)(6)(ii) for storage vessels.
§63.655(e)(1),
§63.655(f)(1)(i)
§63.655(g)(14)
§63.655(h)(6)
§§63.660(g)
A Periodic Report meeting the following requirements shall be met for
storage vessels:
§63.642(f)
§63.655 (e)(2) and (g)
§§63.660(g)
The applicable requirements specified in §63.655(g)(1), (2)(ii), (3)(ii),
or (5) and §63.1066(b) shall be included in the report.
§63.655(g)
Reports shall be submitted to the Department on a semi-annual
calendar basis according to the following reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
§63.642(f)
§63.655(g)
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Provisos for MACT CC: Organic HAP Storage Vessels Federally Enforceable Provisos Regulations
(c) A Periodic Report is not required if no events specified in the
applicable requirements of §63.655(g)(2) through (5) occurred
during the reporting period.
§63.655(g)
§63.655(g)(2)-(5)
Notifications of inspections shall be submitted as specified in §63.655(h)(2)
and as follows:
§63.655(h)(2)
The Department shall be notified of refilling of each Group 1 Storage
vessel that has been emptied and degassed as specified in
§63.655(h)(2)(i) in order to allow for an opportunity to inspect the
storage vessel prior to refilling. Except as specified in
§63.655(h)(2)(i)(B) and (C), notifications shall be provided in writing
at least 30 calendar days prior to filling or refiling each storage vessel
with organic HAPs.
§63.655(h)(2)(i)
In order to allow the Department, the opportunity to observe seal
gap measurements of Group 1 storage vessels equipped with an EFR,
a notification must be submitted in writing at least 30 calendar days
in advance of the measurement. The Department can waive the
notification requirement for all or some storage vessels subject to
this rule or allow less than 30 calendar day notices.
§63.655(h)(2)(ii)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
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121
Summary Page for MACT EEEE: (Non-Gasoline) Organic Liquids Distribution
(OLD) Systems Handling HAPs
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
ORGANIC LIQUID (OLD)(NON-GASOLINE) DISTRIBUTION SOURCES:
STORAGE TANKS
Volatile organic liquid storage
vessels
OHAP Install floating roof
w/seals & maintain seals
§63.2346(a)
[OLD MACT]
WITH INTERNAL FLOATING ROOF:
T-001
T-002
T-092
1,010,096 gallons
1,010,096 gallons
7,116,665 gallons
VOC
VOC
VOC
None
None
83 Tons/Yr
Rule 335-3-14-.04 [Anti-PSD Limit]
WITH EXTERNAL FLOATING ROOF:
T–015
T-091
T-90M
6,908,028 gallons
7,116,665 gallons
2,514,112 gallons
VOC
VOC
VOC
83 Tons/Yr
10 Tons/Yr
None
Rule 335-3-14-.04 [Anti-PSD Limit]
Rule 335-3-14-.04 [Anti-PSD Limit]
FUGITIVE OHAP EMITTING EQUIPMENT, INCLUDING RAILCAR CRUDE OIL LOADING RACK
Valves, pumps, sampling
connections in organic liquid
service prior to process
equipment
OHAP LDAR Program §63.2346(c)
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Provisos for Non-Gasoline OLD Systems Handling HAPs
Federally Enforceable Provisos Regulations
Applicability
Tank Nos.: T-015, T-091, and T-092 each have enforceable limits in place
in order to avoid a review under ADEM Admin. Code r. 335-3-14-.04, “Air
Permits Authorizing Construction in Clean Air Areas [Prevention of
Significant Deterioration (PSD)] and the requirements specified in this
subpart of this permit.
Rule 335-3-14-.04
[Anti-PSD Limit]
Each affected source listed on the summary page of this subpart shall be
subject to the requirements specified in ADEM Admin. Code r. 335-3-16,
“Major Source Operating Permits”, and the requirements specified in this
subpart of this permit.
Rule 335-3-16-.03
Except as specified in §63.2334(c) of 40 CFR 63 Subpart EEEE, “ National
Emission Standards for HAPs: Organic Liquid Distribution (Non-Gasoline)”
[OLD MACT], each piece of equipment listed on the summary page is
subject to the requirements of the OLD MACT and the requirements
specified in this subpart of this permit:
§63.2330
§§63.2334(a) (c)
§§63.2338(a),(d)-(f)
§63.2342
§63.2406
Except as specified in §63.2338(c) of the OLD MACT, affected
sources includes piping, loading/transfer racks, ancillary
equipment, and storage vessels that handle crude oil and are
located upstream of the process and other sources specified in
§63.2338(a) of the OLD MACT.
§§63.2338(a),(b),(c)
§63.2343(a)
The applicable requirements specified in 40 CFR 63, Subpart A,
“General Provisions” [Subpart A] and this subpart of this permit
shall be met as specified in Table 12 of the OLD MACT.
§63.2398
Table 12, OLD MACT
Nothing in this section shall preclude the Permittee from
selecting another compliance option allowed by this subpart,
provided written notice is first supplied to the Department.
Compliance with control options for storage vessels specified in
40 CFR 63, Subpart WW, “National Emission Standard for
Storage Vessels (Tanks)-Control Level 2” [NESHAP WW] shall only
be met as referenced in this subpart.
§63.2346(a)(3)
§63.1060
Compliance with control options for equipment leak
components specified in 40 CFR 63, Subpart TT “National
Emission Standard for Equipment Leaks-Control Level 1”
[NESHAP TT] shall only be met as referenced in this subpart.
§63.1000(a)
§63.2346(c)
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Provisos for Non-Gasoline OLD Systems Handling HAPs
Federally Enforceable Provisos Regulations
Emission Standards
Storage vessel Nos. T-015 and T-092 shall not emit into the atmosphere
volatile organic compound (VOC) emissions in excess of 83 Tons per
twelve (12) consecutive months/storage vessel.
Rule 335-3-14-.04
[Anti-PSD Limit]
Storage vessel No. T-091 shall not emit into the atmosphere volatile
organic compound (VOC) emissions in excess of 10 Tons per twelve (12)
consecutive months.
Rule 335-3-14-.04
[Anti-PSD Limit]
The requirements under the OLD MACT for storage vessels shall be met
by complying with the following emission limitations, operating limits,
and work practice standards at all times when in OLD operation:
§63.2346(a)(3)
§63.2350(a)
(a) For existing Tank Nos.: T-001, T-002, and T-092 storing crude oil
and/or non-crude oil (with a maximum True Vapor Pressure
(TVP) less than 76.6 kilopascals (kPa) (11.1 pounds per square
inch (psia)), compliance with the OLD MACT shall be met by
installing, operating, and maintaining an internal-floating roof
(IFR) in accordance with the requirements specified in §63.1063
of NESHAP WW.
§63.2346(a)(3), OLD MACT
§63.1062(a)(1), NESHAP WW
§60.1063(a)(1)(i), NESHAP WW
Table 2, No. 2, OLD MACT Table
2,No. 1(a)(ii), OLD MACT
Table 4, No. 1(a), OLD MACT
§63.2350(b)
§63.2370
(b) For existing Tank Nos.: T-015 and T-091 and modified tank No.
90M storing crude oil and/or non-crude oil (with a maximum TVP
less than 76.6 kilopascals kPa (11.1 psia)), compliance with the
OLD MACT shall be met by installing, operating, and maintaining
an external floating roof (EFR) in accordance with the
requirements specified in §63.1063 of NESHAP WW.
§63.2346(a)(3), OLD MACT
§63.1062(a)(2), NESHAP WW)
Table 2, No. 2 and 5, OLD MACT
Table 2, No. 1(a)(ii), OLD MACT
Table 4, No. 1(a), OLD MACT
§63.2350(b), §63.2370
(c) An equivalent to the requirements specified in proviso 3(a) or (b)
of this section may be met as specified in §63.1064 of NESHAP
WW.
§63.2346(a)(3), OLD MACT
§63.1062(a)(3), NESHAP WW
Storage vessels equipped with a floating roof to comply with §63.1062 of
NESHAP WW, shall meet the following requirements:
§63.1063
§63.2346(a)(3)
For IFR storage vessels, the design requirements for rim seals
shall be met by equipping the storage vessel with one of the seal
configurations specified in §63.1063(a)(1)(i)(A) through (C),
except as specified in §63.1063(a)(1)(i)(D).
§63.1063(a)(1)(i)(A)-(D)
For EFR storage vessels, the design requirements for rim seals
shall be met by equipping the storage vessel with one of the seal
configurations specified in §63.1063(a)(1)(ii)(A) or (B), except as
specified in §63.1063(a)(1)(ii)(C).
§63.1063(a)(1)(ii)(A)-(C)
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Federally Enforceable Provisos Regulations
For IFR and EFR storage vessels, the design requirements for
deck fittings shall be met as follows:
Equip the opening through the deck of the floating roof
with a fitting as specified in §63.1063(a)(2)(i) through
(viii), except as specified in §63.1063(a)(2)(ix).
§63.1063(a)(2)(i) through (ix)
For IFR and EFR storage vessels, the storage vessel must
meet the operational requirements specified in
§63.1063(b).
§63.1063(b)
For IFR and EFR storage vessels, conditions causing
inspection failures under §63.1063(d) shall comply with
the repair requirements under §63.1063(e).
§63.1063(e)
§63.2378(a)
Table 10, No. 3
Equipment leak component associated with storage vessels that operate
in OLD service for at least 300 hours per year, shall comply with MACT
EEEE by meeting the applicable requirements specified in NESHAP TT at
all times when in OLD operation for each pump, valve (excluding relief
and check valves), and sampling connection.
§63.2346(c)
§63.2350(a)
§63.2406
Table 4, No. 4, MACT EEEE
The standards specified in §63.1006 of NESHAP TT shall be met
for valves in gas and vapor service and in light liquid service.
§63.1006
The standards specified in §63.1007 of NESHAP TT shall be met
for pumps in light liquid service.
§63.1007
The standards specified in §63.1010 of NESHAP TT shall be met
for pumps in heavy liquid service.
§63.1010
The standards specified in §63.1013 of NESHAP TT shall be met
for sampling connection systems.
§63.1013
The standards specified in §63.1015 of NESHAP TT shall be met
for closed vent systems and control devices; or emissions routed
to a fuel gas system or process.
§63.1015
Compliance with the emission standards found in provisos 5 (a)-
(d) of this section can be met by using an enclosed-vented
process unit that meets the requirements of §63.1016 of
NESHAP TT.
§63.1016
Equipment components that are insulated to provide protection
against persistent sub-freezing temperatures are subject to the
“difficult to monitor” provisions in NESHAP TT.
§63.2346(c)
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Provisos for Non-Gasoline OLD Systems Handling HAPs
Federally Enforceable Provisos Regulations
No controls are required for each transfer rack that only unloads organic
liquids (no organic liquids are loaded at the transfer rack); however,
documentation must be maintained as specified in S63.2343 (a) of MACT
EEEE.
§63.2343(a)
An alternative to the emission limitations, operating limits, and work
practice standards under MACT EEEE may be requested as specified in
§63.6(g) of Subpart A.
§63.2346(g)
§63.6(g)
§63.1002(b), §63.1016
Opening of a safety device shall be allowed at any time that it is required
to avoid unsafe operating conditions.
§63.2346(i)
Each affected source must always be operated and maintained, including
air pollution control and monitoring equipment, according to the
provisions in §63.6(e)(1)(i) of subpart A.
§63.2350(b)
§63.6(e)(1)(i)
Each affected source shall be operated in accordance with §63.6(e)(1)
and (3) of Subpart A and §63.2378(b) of MACT EEEE during each startup,
shutdown, or malfunction.
§S63.6(e)(1), (3)
§63.2350(a)
§63.2378(b)
A written startup, shutdown, and malfunction plan shall be developed
and implemented in accordance with the requirements specified in
proviso §63.6(e)(3) of Subpart A.
§63.2350(c)
§63.2378(b)
§63.6(e)(3)
Emission Monitoring
Inspections shall be conducted on storage vessels equipped with floating
roofs that are complying with Subpart WW to comply with MACT EEEE as
follows:
§63.2358(d)
(a) For IFR storage vessels the following requirements shall be met: §63.2378(a)
Table 10, No. 1
Before the initial filling of an IFR storage vessels
inspection shall be conducted as follows:
§63.1063(c)(1)
(i) Visually inspect the floating roof deck, deck
fittings, and rim seals from within the storage
vessel.
§63.1063(d)(1)
(ii) The inspection may be performed entirely from
the top side of the floating roof, as long as there
is visual access to all deck components specified
in §63.1063(a).
§63.1063(d)(1)
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Provisos for Non-Gasoline OLD Systems Handling HAPs
Federally Enforceable Provisos Regulations
(iii) Any of the conditions described in §63.1063
(d)(1)(i) through (d)(1)(v) constitutes inspection
failure.
§63.1063(d)(1)(i)-(v)
Subsequent inspections shall be performed by meeting
the requirements specified in Proviso 1(a)(2)(i) and (ii) of
this section of this subpart:
§63.1063(c)(1)
(i) At least once per year, conduct tank-top
inspections of the IFR by visually inspecting the
floating roof deck, deck fitting, and rim seal
through opening in the fixed roof.
§63.1063(c)(1)(i)(A), (d)(2)
(A) Any of the conditions described in
§63.1063(d)(1)(i) through (d)(1)(iv) of
this section constitutes inspection
failure.
(B) Identification of holes or tears in the rim
seal is required only for the seal that is
visible from the top of the storage
vessel.
(ii) Each time the storage vessel is completely
emptied and degassed, or every 10 years,
whichever occurs first, the IFR shall be inspected
as specified in Proviso 1(a)(1)(i)-(iii) of this
section of this subpart.
§63.1063(c)(1)(i)(B)
Instead of the inspection frequency specified in Proviso
1(a)(2) above, subsequent inspections for storage
vessels equipped with two rim seals may be performed
each time the storage vessel is completely emptied and
degassed, or every 5 years, whichever occurs first, and
according to the requirements specified in Proviso
1(a)(1)(i)-(iii) of this section of this subpart.
§63.1063(c)(1)(ii)
For EFR storage vessels the following requirements shall be met: §63.2378(a)
Table 10, No. 2
To determine the presence and size of gaps between the
rim seals and the wall of the storage vessel the
requirements specified in proviso 1(b)(1)(i) and (ii) of
this section of this subpart shall be met by conducting
seal gap inspections as specified in §60.1063(d)(3)(i) :
§60.1063(d)(3)(i)
127
Provisos for Non-Gasoline OLD Systems Handling HAPs
Federally Enforceable Provisos Regulations
(i) Inspections of the storage vessels primary and
secondary rim seals shall be inspected within 90
days after the initial filling of the storage vessel
§60.1063(c)(2)(i),(d)(3)
(ii) For subsequent testing, the secondary seal of
the EFR shall be inspected at least once every
year and the primary seal of the EFR shall be
inspected at least every 5 years
§60.1063(c)(2)(ii), (d)(3)
(iii) An exceedance of the following gap
requirements shall constitute inspection failure
§60.1063(d)(3)
(A) The ratio of seal gap area to vessel
diameter for the primary seal shall not
exceed 212 square centimeters per
meter of vessel diameter (10 square
inches per foot of vessel diameter) and
the maximum gap width shall not
exceed 3.81 centimeter (1.5 inches)
§60.1063(d)(3)(ii)
(B) Except when the secondary seal must be
pulled back or removed to inspect the
primary seal, the ratio of seal gap area
to vessel diameter for the secondary
seal shall not exceed 21.2 square
centimeters per meter of vessel
diameter (1 square inches per foot of
vessel diameter) and the maximum gap
width shall not exceed 1.27 centimeter
(0.5 inches)
§60.1063(d)(3)(iii)
Each time the storage vessel is emptied and degassed, or
every 10 years, whichever comes first the requirements
specified in Proviso 1(a)(1)(i)-(iii) of this section of this
subpart.
§60.1063(c)(2)(iii)
Provided that it has been determined that it is unsafe to
perform the floating roof inspections in Proviso 1(b)(1)(i)
or (ii) of this section of this subpart, the requirements
specified in §60.1063(c)(2)(iv) shall be met.
§60.1063(c)(2)(iv)
A leak detection and repair (LDAR) program, as specified in NESHAP TT,
shall be implemented for equipment leak components in OLD service.
Table 7, No. 4(a)(i) & Table 10, No.
5 of MACT EEEE
§63.2370(a), §63.2378(a)
§63.1002(a), §63.1003
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Federally Enforceable Provisos Regulations
Leak monitoring shall be conducted as specified in §63.1004 of
NESHAP TT
§63.1004
Leak repair shall be conducted as specified in §63.1005 of
NESHAP TT
§63.1005
Compliance and Performance Test Methods and Procedures
To determine the HAP content of the organic liquid, Method 311 of 40
CFR part 63, Appendix A, or other methods approved by the Department
may be used.
§63.2354(c)
Seal gap inspections conducted to measure rim seals on EFR storage
vessels for gaps must be performed using the procedures specified in
§60.1063 (d)(3)(i) of NESHAP WW.
§60.1063(d)(3)(i)
§63.2358(b)
Table 7, No. 1 & 2, MACT EEEE
§63.2370(a), (c)
Equipment component leaks shall be determined according to Method
21 of 40 CFR 60 Appendix A, and the procedures specified in §63.1004 of
NESHAP TT.
§63.1004
Recordkeeping and Reporting Requirements
A monthly record of the VOC emissions from storage vessels No. T-015,
T-091, and T-092 shall be determined using the following information:
Rule 335-3-14-.04
[Anti-PSD]
The througHPut of each storage vessel
Petroleum liquid (Gallons/Month)
The emission rate for each storage vessel while utilizing the
methods and procedures specified by EPA computer simulator
Tanks 3.0 or 4.1 or the most recent version thereof, or any similar
program for estimating tank emissions.
Individual Vessel Emissions (Lbs/Month)
A twelve (12) consecutive month record of the VOC emissions from each
tank shall be estimated while utilizing the results of the current month
estimates as determined in proviso 1(b) of this section of this subpart
summated with the previous eleven (11) months emission estimates.
Rule 335-3-14-.04
Individual Vessel Emissions (Lbs/12 Months) =
Current month [Individual Vessel Emissions (Lb/Month)] +
∑Previous eleven (11) months [Individual Vessel Emissions (Lb/Month)]
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Provisos for Non-Gasoline OLD Systems Handling HAPs
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Individual Vessel Emissions (Tons/12 Months) =
[ Individual Vessel Emissions (Lbs/12 Months)]
[ 2000 Lbs/Ton ]
Periodic Monitoring Reports (PMR) meeting the requirements specified
in proviso 3(a) and (b) of this section of this subpart shall be submitted
to the Department.
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups, shutdowns, and malfunctions.
A deviation shall mean any condition determined by
observation, by data collected by any continuous
monitoring system or periodic monitoring required by
the permit that can be used to determine compliance,
that identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If no deviation event occurred during reporting period, a
statement that indicates there were no deviations from
the permit requirement requirements shall be included
in the report.
Except as provided for in proviso 3(c) of this section, the report
shall include the information specified in proviso 3(b)(1) of this
section of this subpart.
For each deviation event, the following information shall
be submitted.
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
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Provisos for Non-Gasoline OLD Systems Handling HAPs
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(viii) Actions taken to return to normal operating
conditions
(ix) Total operating hours of the affected source
during the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period
and shall be submitted according to the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 3(b) of this section may
be modified upon receipt of Departmental approval.
The following recordkeeping and reporting requirements shall be met for
to demonstrate compliance with MACT EEEE:
Applicable notifications specified in §63.2342(d), §63.2382,
§63.2386, §63.2390, and §63.2394 of MACT EEEE,
§63.1066(b)(1) of NESHAP WW, and §63.1018(b) of NESHAP TT.
§63.2342(d)
§63.2382, §63.2386
§63.2390, §63.2394
§63.1018(b)
§63.1066(b)(1)
Applicable records specified in §63.1065 of Subpart WW found
below shall be maintained for storage vessels equipped with a
floating roof:
§63.1065
§63.2390(b)(2)
Table 10 No. 1-3
Records of the vessel dimension and capacity as
specified in §63.1065(a)
§63.1065(a)
Records of inspection results as specified in §63.1065(b) §63.1065(b)
§63.1066(b)(2)
Records of floating roof landing as specified in
§63.1065(c)
§63.1065(c)
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Documentation of extensions used in accordance with
§63.1065(e)(2) or §63.1065(c)(2)(iv)(B)
§63.1065(d)
The applicable recordkeeping requirements specified in
§63.1016(b) of NESHAP TT, if an alternate means of emission
limitation is elected, or §63.1017 of NESHAP TT must be
maintained for equipment components.
§63.1016(b)
§63.1017
Documentation demonstrating that no controls are required on
transfer racks that only unload at a facility must be maintained
as follows to demonstrate compliance with MACT EEEE:
§63.2343(a)
Must be kept up-to-date and in a form suitable and
readily available for expeditious inspection and review
according to §63.10(b)(1) of Subpart A, including records
stored in electronic form in a separate location.
The documentation may consist of identification of the
transfer racks on a plant site plan or process and
instrumentation diagram (P&ID).
Copies of all applicable files (including all reports and
notifications) shall be maintained for at least 5 years following
the date of each occurrence, measurement, maintenance,
corrective action, report, or record.
§63.2394(b), (c)
§63.1065
You must keep each record on site for at least 2 years
after the date of each occurrence, measurement,
maintenance, corrective action, report, or record.
You may keep the records offsite for the remaining 3
years.
All applicable records shall be maintained in a form suitable and
readily available for expeditious inspection and review according
to §63.10(b)(1), including records stored in electronic form at a
separate location
§63.10(b)(1)
§63.2394(a)
§63.1065
Records may be maintained in hard copy or computer-readable
form including, but not limited to, on paper, microfilm,
computer, flash drive, floppy disk, magnetic tape, or microfiche.
§63.1065
The following reports shall be submitted to demonstrate compliance
with the MACT EEEE:
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Provisos for Non-Gasoline OLD Systems Handling HAPs
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A Compliance Report shall include the applicable information
specified in §63.8693(c)(1)-(9) and the applicable information
specified in §63.8693(d).
§63.2386(c), (d)
A Periodic Report shall include the information specified in
§63.1066(b) of NESHAP WW to demonstrate compliance with
MACT EEEE for storage vessels
§63.1066(b)
A Periodic Report shall include the information specified in
§63.1018(a) of NESHAP TT to demonstrate compliance with
MACT EEEE for equipment components
§63.1018(a)
Each report shall cover a semi-annual reporting period and shall
be submitted according to the following reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1- December 31 February 28
§63.2386(b)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso
15(b) and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
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Summary Page for NSPS GGG: Fugitive Equipment Leaks
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
AFFECTED COMPONENTS:
Group of Equipment (valves, pumps,
pressure relief devices, sampling
connection systems, open-ended valve
or line, and flanges or other
connectors) within a process unit
Compressors (except those in hydrogen
service)
VOC
BZ
VHAPs
OHAP
LDAR Program §60.592 [NSPS GGG]
§60.482 [NSPS VV]
Rule 335-3-16-.05(a)
INDIVIDUAL PROCESS UNITS [OHAP & VOC SERVICE]:
Diesel Hydrotreater
No. 1 Hydrogen Plant
No. 1 Platformer
No. 1, No. 2, & No. 3 Merox Units
Kerosene Hydrotreater
Naphtha Unifiner
Stoddard Tower
Sour Water Stripper
ISOM Unit
Naphtha Hydrobon
Crude Unit Closed Vent System & Flare
Hydrobon Unit Closed Vent System & Flare
Gasoline Loading Rack Closed Vent System & Vapor Combustor
MISCELLANEOUS LOADING RACKS [OHAP & VOC SERVICE], PRE-1973:
Diesel
Old 8A Tank
7A Tank
Double bay
Specialty
Cutback (T36-T39)
North Emulsion
South Emulsion
Tank 14 spout
Tank 50 spout
Marine dock
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Provisos for Summary Page for Fugitive Equipment Leaks
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Applicability
Each component of each process unit specified on the summary page
of this subpart shall be subject to the requirements specified in ADEM
Admin. Code r. 335-3-16, “Major Source Operating Permits”, and the
requirements specified in this subpart of this permit.
Rule 335-3-16-.03
The group of all equipment within a process unit and each compressor
will be subject to the requirements of 40 CFR Part 60, Subpart GGG,
“Standards of Performance for Equipment Leaks of VOC in Petroleum
Refineries” and the requirements of this subpart of this permit.
§60.590, NSPS GGG
Compliance with NSPS GGG will demonstrate compliance with
the requirements specified in 40 CFR Part 63 Subpart CC,
“National Emission Standards for Hazardous Air Pollutants
(HAPs) Emissions from Petroleum Refineries”, [Refinery MACT
1/MACT CC].
§63.640(p)(2)
NSPS GGG
Existing facilities shall comply with the equipment leak
requirements of 40 CFR 60 Subpart GGG, "Standards of
Performance for Equipment Leaks of VOC in Petroleum
Refineries", [NSPS GGG] instead of the requirements in 40 CFR
Part 61, Subparts J and V, Part 63, Subparts F, H, and CC, and
ADEM Admin. Code r. Rule 335-3-6-.21 leak detection and
repair (LDAR) requirements that are federally enforceable.
Rule 335-3-16-.05(a)
Except as specified in §60.593 of NSPS GGG, the applicable
requirements of 40 CFR 60 Subpart VV, “Standards of
Performance for Equipment Leaks of VOC in the Synthetic
Organic Chemicals Manufacturing Industry” [NSPS VV] by
reference, shall demonstrate compliance with NSPS GGG.
§60.592(a), (b)(1) & (2)
§60.593, NSPS GGG
The applicable requirements under 40 CFR 60, Subpart A,
"General Provisions" [Subpart A] shall be met as specified in
NSPS VV and as specified in this subpart of this permit, except
that §60.7(b) and (d) of Subpart A do not apply to affected
facilities under NSPS VV.
40 CFR 60 Subpart A
§60.486(k)
Covered components under NSPS GGG shall include the
following:
§60.590(a)
Each compressor
Each valve
Each pump
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Each pressure relief device
Each sampling connection system
Each instrumentation system
Each open-ended valve or line
Each flange or other connector in VOC service
Process units shall mean components assembled to produce
intermediate or final products from petroleum, unfinished petroleum
derivatives, or other intermediates; a process unit can operate
independently if supplied with sufficient feed or raw materials and
sufficient storage facilities for the product.
§60.590(e)
Emission Standards
Except as provided for in §60.484 of NSPS VV for equivalent means of
emission limitations, each affected process unit component shall
comply with the following requirements:
§60.592(a)-(e)
§60.593
(a) Each compressor shall comply with the requirements specified
in §60.482-3 of NSPS VV, except that:
§60.592(a)
§60.482-1
§60.482-3
Compressors proven to be in hydrogen service, as
determined using the requirements specified in
§60.593(b) of NSPS GGG, are exempt from the
requirements of §60.592 of NSPS GGG.
§60.593(b)
Any existing compressor that has been modified or
reconstructed is exempt from the applicable
requirements of §60.482-3 of NSPS VV as specified in
§60.593(c) of NSPS GGG, provided that it can be
demonstrated that recasting the distance piece or
replacing the compressor are the only options to bring
the compressor in compliance.
§60.593(c)
Each valve shall comply with the requirements specified in
§60.482-7 of NSPS VV for valves in gas/vapor and light liquid
service and §60.482-8 of NSPS VV for valves in heavy liquid
service, except that the methods specified in §60.592(b) of
NSPS GGG may be elected as an alternative.
§60.592(a), §60.482-1
§60.482-7, §60.482-8
§60.592(b)
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Each pump shall comply with the requirements specified in
§60.482-2 of NSPS VV for pumps in light liquid service and
§60.482-8 of NSPS VV for pumps in heavy liquid service.
§60.592(a), §60.482-1
§60.482-2, §60.482-8
Each pressure relief device (PRD) shall comply with the
requirements specified in §60.482-4 of NSPS VV for a PRD in
gas/vapor service and §60.482-8 of NSPS VV for a PRD in light
or heavy liquid service.
§60.592(a), §60.482-1
§60.482-4, §60.482-8
Each sampling connection system shall comply with the
requirements specified in §60.482-5.
§60.592(a), §60.482-1
§60.482-5
Each open-ended valves or lines shall comply with §60.482-6
of NSPS VV, except that those containing asphalt are exempt
from the requirements of §60.482-6(a) through (c) of NSPS VV
§60.592(a), §60.482-1
§60.482-6, §60.592(f)
Each connector shall comply with the requirements specified
in §60.482-8 of NSPS VV.
§60.592(a), §60.482-1,
§60.482-8
Delay of repair shall be allowed if applicable conditions
stipulated in §60.482-9 are met.
§60.592(a), §60.482-1
§60.482-9
A closed vent system (CVS) and control device used to comply
with any of the above requirements, shall comply with the
requirements specified in §60.482-10 of NSPS VV.
§60.592(a), §60.482-1
§60.482-10
Compliance and Performance Test Methods and Procedures
Except as specified in 60.593(d) of NSPS GGG, the test methods and
procedure specified in §60.485 of NSPS VV may be utilized.
§60.8
§60.482-1(b), §60.485,
§60.485(e)
§60.592(a), (e), §60.593(d)
Emission Monitoring
The inspection and monitoring requirements specified in §60.482-1
through §60.482-10 of NSPS VV and either §60.483-1 or §60.483-2 of
NSPS VV shall be complied to demonstrate compliance with NSPS GGG.
§60.482-1(b)
§60.592(a), (b)
Recordkeeping and Reporting Requirement
The recordkeeping requirements specified in §60.7 and §60.19 of
Subpart A and §60.486 of NSPS VV shall be maintained for a period of
five (5) years, made available for inspection, and submitted to the
Department when required. Records shall include the following:
§60.482-1(b)
§60.486
§60.592(e)
Rule 335-3-16-.05(a)
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Provisos for Summary Page for Fugitive Equipment Leaks
Federally Enforceable Provisos Regulations
(a) Records of each leak detected as specified in §60.486(b)(1)
through (3) of NSPS VV.
§60.486(b)(1)
(b) Record of the information specified in §60.486(c)(1) through
(9) of NSPS VV shall be recorded in a log and shall be kept for
two years in a readily accessible location.
§60.486(c)(1)-(9)
(c) Records pertaining to the design requirements for CVS and
control devices shall be maintained as specified in
§60.486(d)(1) through (5) of NSPS VV.
§60.486(d)(1)-(5)
(d) The applicable information specified in §60.486(e),
§60.486(f), §60.486(h), §60.486(j), and the exemptions
specified in 60.486(i) of NSPS VV shall be recorded in a log that
is kept in a readily accessible location.
§60.486(e), (f),(h), (i), (j)
(e) The information specified in §60.486(g) of NSPS VV shall be
maintained for valves complying with §60.483-2 of NSPS VV.
§60.486(g)
A semi-annual report meeting the following requirement shall be
submitted to demonstrate compliance with NSPS GGG:
§60.482-1(b)
§60.487
§60.592(e)
Reports shall include the information specified in §60.487(c)(1)
through (4) of NSPS VV.
§60.487(c)
Records of each deviation event shall be included in the report. Rule 335-3-16-.05(c)2
Rule 335-3-16-.05(c)3(i)
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the
permit that can be used to determine or indicate
compliance, that identifies an affected source has
failed to meet an applicable emission limit or standard,
or that a work practice was not complied with or
completed.
If there are no deviations events that occurred during
the reporting period, a statement that indicates there
were no deviations from the permit requirements
shall be included in the report.
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Each report shall be submitted to the Department on the
following reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1 - December 31 February 28
§60.487(a), (b), (c)
Rule 335-3-16-.05(c)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the General Provisos subpart
of this permit.
Rule 335-3-16-.05(c)3(ii)
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Summary Page for NSPS GGGa: Fugitive Equipment Leaks of VOC & OHAP
Emissions
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
AFFECTED COMPONENTS:
Group of Equipment (valves, pumps,
pressure relief devices, sampling
connection systems, open-ended valve
or line, and connectors) within a
process unit
Compressors (except those in hydrogen
service)
VOC
VOC & OHAP
OHAP
LDAR Programs §60.482a [NSPS VVa]
Rule 335-3-6-.21
§60.592a [NSPS GGGa]
INDIVIDUAL PROCESS UNITS [VOC & OHAP SERVICE]:
Hydrocracker Unit
Hydrocracker Unit Closed Vent System & Flare
CCR Platformer
No. 2 Hydrogen Plant
No. 1 Amine Unit
No. 2 Amine Unit
Delayed Coking Unit
Wastewater Treatment Plant
Coker Unit Closed Vent System & Flare
Bio-Fuel Blending System
No. 1 Sulfur Recovery System & Thermal Oxidizer
No. 2 Sulfur Recovery System & Thermal Oxidizer
Railcar Loading Rack
Crude Unit (Modified)
Flexible Hydrotreater
140
Provisos for Fugitive Equipment Leaks of VOC & OHAP Emissions
Federally Enforceable Provisos Regulations
Applicability
Each component of each process unit specified on the summary page of
this subpart shall be subject to the requirements specified in ADEM Admin.
Code r. 335-3-16, “Major Source Operating Permits”, and the requirements
specified in this subpart of this permit.
Rule 335-3-16-.03
Except as specified in §60.593a, each component of each process unit
specified on the summary page of this subpart shall comply with the
equipment leak requirements of 40 CFR 60 Subpart GGGa, "Standards of
Performance for Equipment Leaks of VOC in Petroleum Refineries" [NSPS
GGGa] and this subpart of this permit.
§60.590a(a), (b)
§60.593a
Overlap of NSPS GGGa with equipment leak standards specified in
§63.648 of 40 CFR Part 63, Subpart CC, “National Emission
Standards for Hazardous Air Pollutants (HAPs) Emissions from
Petroleum Refineries” [Refinery MACT 1/MACT CC], requires
compliance only with NSPS GGGa, except that pressure relief
devices in organic HAP service must only comply with the
requirements in §63.648(j) of MACT CC.
§63.640(p)(2)
§63.648(j)
Overlap with NSPS GGGa with equipment leak standards specified
in ADEM Admin. r. 335-3-6-.21, "Leak from Petroleum Refinery
Equipment" requires compliance with the NSPS GGGa provided
that the requirements of ADEM Admin. r. 335-3-10-.01(2)(a) and
(b) are met.
Rule. 335-3-10-.01(2)
§63.640(q)
Compliance with 40 CFR 60 Subpart VVa, “Standards of
Performance for Equipment Leaks of VOC in the Synthetic Organic
Chemicals Manufacturing Industry” [NSPS VVa] by reference, shall
demonstrate compliance with NSPS GGGa for existing sources.
§60.592a
The applicable requirements under 40 CFR 60, Subpart A, "General
Provisions" [Subpart A] ,shall be met as specified in NSPS VVa and
as specified in this subpart of this permit ,except that §60.7(b) and
(d) of Subpart A do not apply to affected facilities under this
subpart.
40 CFR 60 Subpart A
§60.486a(k)
Covered components under NSPS GGGa shall include the
following:
§60.590a(a)
§60.591a
Each compressor
Each valve
Each pump
141
Provisos for Fugitive Equipment Leaks of VOC & OHAP Emissions
Federally Enforceable Provisos Regulations
Each pressure relief device
Each sampling connection system
Each open-ended valve or line
Each connector
Process units shall mean components assembled to produce intermediate
or final product from petroleum, unfinished petroleum derivates, or other
intermediates; a process unit can operate independently if supplied with
sufficient feed or raw materials and sufficient storage facilities for the
product.
§60.590a(e)
Emission Standards
Except as provided for in §60.484a of NSPS VVa for equivalent means of
emission limitations, each affected process unit component shall comply
with the following requirements:
§60.592a(a)-(e)
§60.593a
(a) Each compressor shall comply with the requirements specified in
§60.482-3a of NSPS VVa, except that:
§60.592a(a)
§60.482-1a
§60.482-3a
Compressors proven to be in hydrogen service, as
determined using the requirements specified in
§60.593a(b) of NSPS GGGa, are exempt from the
requirements of 60.529a of NSPS GGGa.
§60.593a(b)
Any existing compressor that has been modified or
reconstructed is exempt from the applicable requirements
of §60.482-3a of NSPS VVa as specified in §60.593a(c) of
NSPS GGGa, provided that it can be demonstrated that
recasting the distance piece or replacing the compressor
are the only options to bring the compressor in
compliance.
§60.593a(c)
§60.488a
Each valve shall comply with the requirements specified in
§60.482-7a of NSPS VVa for valves in gas/vapor and light liquid
service and §60.482-8a of NSPS VVa for valves in heavy liquid
service, except that the methods specified in §60.592a(b) of NSPS
GGGa may be elected as an alternative.
§60.592a(a), §60.482-1a
§60.482-7a, §60.482-8a
§60.592a(b)
Each pump shall comply with the requirements specified in
§60.482-2a of NSPS VVa for pumps in light liquid service and
§60.482-8a of NSPS VVa for pumps in heavy liquid service.
§60.592a(a), §60.482-1a
§60.482-2a, §60.482-8a
§60.592a(b)
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Provisos for Fugitive Equipment Leaks of VOC & OHAP Emissions
Federally Enforceable Provisos Regulations
Except as specified in §63.648(j)(4) of MACT CC, each pressure
relief device (PRD) (such as relief valves or rupture disks) in organic
HAP gas or vapor service shall comply with the requirements
specified in §63.648(j) of MACT CC instead of those specified in
§60.482-4a of NSPS VVa.
§63.640(p)(2), MACT CC
§63.648(j), MACT CC
Each sampling connection system shall comply with the
requirements specified in §60.482-5a.
§60.592a(a)
§60.482-1a
§60.482-5a
Each open-ended valves or lines shall comply with §60.482-6a of
NSPS VVa, except that those containing asphalt are exempt from
the requirements of §60.482-6a(a) through (c) of NSPS VVa.
§60.592a(a), §60.482-1a
§60.482-6a, §60.591a
§60.593a(f)
Except as specified in §60.593a(g) of NSPS GGGa and as specified
in §63.649 of MACT CC, each connector shall comply with §60.482-
8a of NSPS VVa.
§60.482-1a, §60.482-8a
§63.649, §60.592a(a)
§60.593a(g)
Delay of repair shall be allowed if applicable conditions stipulated
in 60.482-9a are met.
§60.592a(a)
§60.482-1a
§60.482-9a
A closed vent system (CVS) and control device used to comply with
any of the above requirements, shall comply with the
requirements specified in §60.482-10a of NSPS VVa.
§60.592a(a)
§60.482-1a
§60.482-10a
Compliance and Performance Test Methods and Procedures
Except for equipment in light liquid service as specified in §60.593a(d) of
NSPS GGGa, the test methods and procedure specified in §60.485a of NSPS
VVa may be utilized.
§60.8
§60.485a, §60.485a(e)
§60.482-1a(b)
§60.592a(a), (e, §60.593a(d)
Emission Monitoring
The inspection and monitoring requirements specified in §60.482-1a
through §60.482-10a of NSPS VVa and either §60.483-1a or §60.483-2a of
NSPS VVa shall be complied with to demonstrate compliance with NSPS
GGGa, except as specified in §60.593a of GGGa.
§60.482-1a(b)
§60.592a(a), (b)
§60.593a
Recordkeeping and Reporting Requirement
The recordkeeping requirements specified in §60.7 and §60.19 of Subpart
A and §60.486a of NSPS VVa shall be maintained for a period of 5 years,
made available for inspection, and submitted to the Department when
required. Records shall include the following information:
§60.482-1a(b)
§60.486a
§60.592a(e)
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Provisos for Fugitive Equipment Leaks of VOC & OHAP Emissions
Federally Enforceable Provisos Regulations
Records specified in §60.486a(3)(i)-(v) of NSPS VVa for each
required monitoring event
§60.486a(a)(3)
Records of each leak detected as specified in §60.486a(b)(1)
through (4) of NSPS VVa
§60.486a(b)(1)
Records of the information specified in §60.486a(c)(1) through (9)
of NSPS VVa shall be recorded in a log and shall be kept for two
years in a readily accessible location
§60.486a(c)(1)-(9)
Records pertaining to the design requirements for CVS and control
devices shall be maintained as specified in §60.486a(d)(1) through
(5) of NSPS VVa
§60.486a(d)(1)-(5)
The applicable information specified in §60.486a(e), §60.486a(f),
§60.486a(h), §60.486a(j), and the exemptions specified in
§60.486a(i) of NSPS VVa shall be recorded in a log that is kept in a
readily accessible location
§60.486a(e), (f),(h), (i), (j)
The information specified in §60.486a(g) of NSPS VVa shall be
maintained for valves complying with §60.483-2a of NSPS VVa
§60.486a(g)
The following reporting requirements shall be met:
(a) A semi-annual report meeting the following requirement shall be
submitted to demonstrate compliance with NSPS VVa and GGGa:
§60.482-1a(b)
§60.487a, §60.59a2(e)
Initial reports shall include the information specified in
§60.487a(b)(1) through (4) of NSPS VVa.
§60.487a(b)
Subsequent reports shall include the information specified
in §60.487a(c)(1) through (4) of NSPS VVa.
§60.487a(c)
Records of each deviation event shall be included in the
report.
Rule 335-3-16-.05(c)2
Rule 335-3-16-.05(c)3(i)
(i) A deviation shall mean any condition determined
by observation, by data derived from any
monitoring or testing or recordkeeping which is
required by the permit that can be used to
determine or indicate compliance, that identifies
an affected source has failed to meet an applicable
emission limit or standard, or that a work practice
was not complied with or completed.
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(ii) If there are no deviations events that occurred
during the reporting period, a statement that
indicates that there were no deviations from the
permit requirements shall be included in the
report.
Each report shall be submitted to the Department on the following
reporting schedule:
Reporting Period Submittal Date
January 1 - June 30 August 28
July 1 - December 31 February 28
§60.487a(a), (b),(c), (f)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
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Summary Page for MACT CC: Gasoline Loading Rack and Vapor Combustor
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
TRUCK GASOLINE LOADING RACK TOC
(as VOC)
10 mg of TOC per L of gasoline
loaded §63.650(a)
VOC Work Practice-- Air Sticker Rule 335-3-6-.06(3)
Rule 335-3-6-.20(4)
CLOSED VENT SYSTEM ASSOCIATED WITH THE
GASOLINE LOADING RACKS
(INCLUDING PIPING, FLANGES, ETC)
VOC LDAR Program-- Complying with
requirements under the MACT
CC: Fugitive Equipment Leaks of
OHAP and VOC subpart of this
permit
§60.592(a)
[NSPS GGG]
ZCT2-8-35X-3/8 GASOLINE VAPOR
COMBUSTOR UNIT (VCU)
Opacity No more than one 6 min avg>
20%
OR
No 6 min avg. > 40% in any sixty
(60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
SO2 When burning fuel gas:
H2S <= 162 ppmv over a 3-hour
averaging period
§60.104(a)(1)
[NSPS J]
Rule 335-3-16-.05(a)
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Applicability
The gasoline vapor combustor unit (VCU) shall be subject to the
applicable requirements of ADEM Admin. Code r. 335-3-4-.01, “Visible
Emissions”, and the requirements specified in this subpart of this
permit.
Rule 335-3-4-.01
The gasoline loading rack vapor collection system shall be subject to
the requirements of ADEM Admin. Code r. 335-3-6-.20(4)(a), “Air
Permits for Gasoline Tank Trucks”, and the requirements specified in
this subpart of this permit.
Rule 335-3-6-.06(3)(e)
Rule 335-3-6-.20(4)
The gasoline loading rack and gasoline VCU located at the refinery shall
be subject to the requirements specified in ADEM Admin. Code r. 335-
3-16, “Major Source Operating Permits”, and the requirements
specified in this subpart of this permit.
Rule 335-3-16-.03
§63.642(a)
The gasoline VCU shall be subject to the applicable requirements
specified in 40 CFR Part 60, Subpart A, “General Provisions”, 40 CFR
Part 60, Subpart J, “Standards of Performance for Petroleum
Refineries” [NSPS J], for fuel gas combustion devices and the
requirements specified in this subpart of this permit. Compliance with
NSPS J shall satisfy the requirements of ADEM Admin. Code r. 335-3-4-
.03.
§60.100(a) and (b)
§60.101(g)
Rule 335-3-16-.05(a)
Equipment leaks from fugitive components associated the gasoline
truck loading rack shall comply with the requirements specified in 40
CFR Part 63, Subpart CC, “National Emission Standards for Hazardous
Air Pollutants (HAPs) Emissions from Petroleum Refineries” [MACT CC],
and the requirements specified in the NSPS GGG: Fugitive Equipment
Leaks of OHAP and VOC subpart of this permit. No further
requirements will be included under this subpart of this permit.
§63.640(p)(1), (r)
§63.648
Except as provided for in §63.640(d) and (g) of MACT CC, each gasoline
loading rack subject to the requirements of MACT CC shall meet the
following requirements:
§63.640(a), (c)(5), (d), (g)
§63.641
§63.642(i), (j), (l)
§63.652, §64.2(b)(1)(i)
The requirements specified in §63.640(a) of MACT CC §63.640(a)(1), (2)
Demonstrate compliance with the requirements of ADEM
Admin. Code r. 335-3-6-.06 for bulk gasoline terminals and the
ancillary equipment, except as specified in ADEM Admin. Code
r. 335-3-6-.06(3)(e) by complying with MACT CC.
Rule 335-3-6-.06
§63.640(q)
Each Group 1 gasoline loading rack located within a contiguous
area and under common control with a petroleum refinery
§63.650(a)
§63.422
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shall comply with the applicable regulations under 40 CFR 63,
Subpart R, “NESHAP emissions for Gasoline Distribution
Facilities (Bulk Gasoline Terminals and Pipeline Breakout
Stations)” [NESHAP R], by reference as specified in §63.650(a)
of MACT CC and this subpart of this permit.
§60.502(a), (d), (e)-(g)
The applicable portions of NESHAP R are §63.421,
§63.422(a)-(c) and (e), §63.425(a)–(c), §63.425(e)-(h),
§63.427(a) and (b), §63.428(b), (c), (g)(1), (h)(1)-(3),
and (k).
§63.650(a)
All terms not defined in §63.641 of MACT CC shall have
the meaning given them in 40 CFR part 63, Subpart A
or in NESHAP R. The §63.641 definition of “affected
source” applies under MACT CC.
§63.650(b)
Gasoline loading racks are subject to the provisions of
40 CFR Part 60, Subpart XX, “Standards of Performance
for Gasoline Terminal” [NSPS XX], by reference as
specified in §63.650(a) of MACT CC and §63.422(a) of
NESHAP R and in this subpart of this permit.
§63.422(a)
§63.650(a)
The requirements specified in §60.502 of NSPS XX shall
be met except as specified in §60.502(b), (c), and (j) of
NSPS XX.
Each gasoline loading rack shall be subject to the applicable
requirements specified in Table 6 of MACT CC, in 40 CFR 63
Subpart A, “General Provisions”, and this subpart of this
permit.
§63.642(c)
Table 6, 40 CFR 63, Subpart CC
Per §64.2(b)(1)(i), the VCU would be exempt from the requirements of
40 CFR 64, “Compliance Assurance Monitoring” [CAM]. Compliance
with MACT CC shall meet the requirements of CAM.
§64.2(b)(1)(i)
Emission Standards
Visible emissions from the gasoline vapor combustor unit (VCU) shall
meet the opacity standards specified in proviso 1(a) and (b) of this
section of this subpart.
Rule 335-3-4-.01(a), (b)
The unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 20%, as determined by
a 6-minute average.
Rule 335-3-4-.01(1)(a)
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Except for one 6-minute period during any 60-minute period,
the unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
Only gasoline cargo tanks which have a valid Air Sticker may be loaded
at the gasoline loading rack.
Rule 335-3-6-.06(3)(e)
Rule 335-3-6-.20(4)
§63.422(c), §60.502(a)
The gasoline loading rack VCU shall not combust any fuel gas, as
defined in §60.101(d) of NSPS J, that contains H2S in excess of 162 parts
per million (ppmv) as determined hourly on a three hour rolling
average basis.
§60.104(a)(1)
Rule 335-3-16-.05(a)
The gasoline loading rack shall be equipped with a vapor collection
system designed to collect the total organic compounds (TOC)
displaced from gasoline cargo tanks during product loading. The
collection system shall comply with the following standards:
§60.502(a)
§63.422(a)
Rule 335-3-6-.20(3)(a)
The vapor collection system shall prevent the collected vapors
from passing from one loading rack to another loading rack.
§60.502(a), (d)
Rule 335-3-6-.20(3) and (7)
Loading of liquid product into the gasoline cargo tank shall be
limited to vapor-tight gasoline cargo tanks meeting the
requirements specified in §60.502(e) of NSPS XX.
Rule 335-3-6-.20(3)(a), (4)(a), (7)
§60.502(a), (e)
§63.422(a)
The loading of gasoline cargo tanks shall only be made into
tanks equipped with vapor collection equipment that is
compatible with the terminal’s vapor collection system.
Rule 335-3-6-.20(3)(a), (4)(a)
§60.502(a), (f)
§63.422(a)
The terminal and the cargo tank’s vapor collection system shall
be connected during each loading of a gasoline cargo tank.
Rule 335-3-6-.20(5)
§60.502(a), (g)
§63.422(a)
The vapor collection and liquid loading equipment shall be
designed and operated to prevent gauge pressure in the
delivery tank from exceeding 4,500 pascals (450 mm of water)
during product loading. This level is not to be exceeded when
measured by the procedures specified in §60.503(d) of NSPS
XX.
Rule 335-3-6-.20(5)(a)(1)
§60.502(a), (h)
§63.422(a)
No pressure-vacuum vent in the bulk gasoline terminal's vapor
collection system shall begin to open at a system pressure less
than 4,500 pascals (450 mm of water).
Rule 335-3-6-.20(5)
§60.502(a), (i)
§63.422(a)
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As an alternative to complying with requirements specified in
proviso 4 (e) and (f) of this section of this permit, the
requirements specified in §63.422(e) of NESHAP R may be met.
§63.422(e)
Emissions to the atmosphere from the vapor collection and processing
systems due to the loading of gasoline cargo tanks shall not exceed 10
milligrams of total organic compounds per liter (mg/L) of gasoline
loaded
§63.422(b)
§63.427(b)
The gasoline VCU firebox temperature shall be maintained
above the minimum temperature established during the latest
performance test conducted on the unit.
Operation of the vapor processing system in a manner falling
below the established gasoline VCU firebox temperature shall
constitute a violation of this emission standard.
The applicable requirements specified in §63.648 of MACT CC shall
apply at all times.
§63.642(b)
§63.648
At all times, the gasoline loading rack must be operated and
maintained, including associated air pollution control equipment and
monitoring equipment, in a manner consistent with safety and good
air pollution control practices for minimizing emissions as specified in
§63.642(n) of MACT CC.
§63.642(n)
Rule 335-3-16-.05(a)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards shall be determined using
Method 9 or Method 22 of 40 CFR 60 Appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
Provided that the assist gas combusted in the vapor combustor is the
same as the fuel gas used in the heaters and boilers, the Permittee may
elect to use heater and boiler records to satisfy the test requirements
for the assist gas. Otherwise, performance evaluations of the H2S
monitor shall follow the procedures specified under §60.106(e)(1).
Rule 335-3-16-.05(c)(1)(i) and (ii)
§60.105(a)(4)(ii)
§60.106(e)(1)
The gasoline VCU (thermal oxidation system other than a flare) shall be
equipped with a continuous parameter monitoring system (CPMS)
meeting the following requirements:
§63.427(a)(3)
Must be installed, calibrated, certified, operated, and
maintained, according to manufacturer's specifications,
§63.427(a)
Must be capable of measuring temperature §63.427(a)(3)
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Must be installed in the firebox or in the ductwork immediately
downstream from the firebox in a position before any
substantial heat exchange occurs.
§63.427(a)(3)
The vapor processing system shall be operated in a manner not
to go below the firebox temperature established during the
latest performance test that showed compliance with the
limit.
§63.427(b)
To demonstrate compliance with MACT CC, the test methods and
procedures specified below shall be met:
§63.425(a)-(c), (e)-(i)
A performance test must be conducted on the vapor
processing and collection systems using the methods and
procedures specified in §63.425(a)(1) of NESHAP R to
demonstrate that emissions to the atmosphere from gasoline
loading does not exceed 10 mg of TOC/Liter of gasoline loaded.
§63.425(a)(1)
Volume of air-vapor mixture exhausted (Vesi) shall be
determined using Method 2B of 40 CFR 60 Appendix A for
combustion vapor processing systems, OR Method 2A of 40
CFR 60 Appendix A for any other type system.
§60.503(c)(4), (5)
§63.425(a)(1)
Average Concentration of Total Organic Compounds (Cei) shall
be determined using Method 18, Method 25A, Method 25B of
40 CFR 60 Appendix A or another EPA-approved method.
Methane and Ethane may be excluded when appropriate.
§63.425(a)(1)
§60.503(c)(4), (6)
For a leak detection test, Method 21 of 40 CFR 60 Appendix A-
7 (section 4.3.2 of Method 21 shall be omitted) and the
procedures specified in specified in §63.425(f)(2) of NESHAP R
shall be used.
§63.425(f)(2)
§63.650(a)
§60.503(b)
Emission Monitoring
Provided that visible emissions in excess of the opacity standards occur
from the gasoline VCU, a visible emissions observation must be
conducted to determine opacity or to determine presence of fugitive
emissions from the unit as specified in Appendix B: Gasoline Loading
Rack and Combustor Monitoring section of this permit.
Rule 335-3-16-.05(c)(2)
A vapor collection system shall not load or cause loading to a gasoline
tank truck without a valid Air Sticker for the gasoline tank truck as
specified in ADEM Admin Code r. 335-3-6-.20(4).
Rule 335-3-6-.20(4)(a), (b)
Rule 335-3-16-.05(c)(2)
§63.502(e)(5)
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An Air Sticker may be obtained once the requirements for a
vapor tightness test as specified in ADEM Admin Code r. 335-
3-6-.20(4) are satisfied.
Rule 335-3-6-.20(4)(a)
An Air Permit and Air Sticker shall be issued by the Department
OR by the Jefferson County Department of Health.
Rule 335-3-6-.20(4)(a),(b)
The Air Sticker shall be renewed annually Rule 335-3-6-.20(4)(c)
A valid Air Sticker must be attached and visibly be displayed
near the Department of Transportation Certification plate
required by 49 CFR 178.340-10b.
Rule 335-3-6-.20(3)(b), (4)(d)
A monitoring system that meets the requirements specified in the
§60.15(a)(4) of NSPS J and §60.13 of Subpart A shall be installed,
calibrated, maintained, and operated.
Rule 335-3-16-.05(c)(1)(ii)
§60.13
§60.105(a)(4)
§60.105(a)(4)(ii)
Periodic monitoring as specified in Appendix B: Gasoline Loading Rack
and Combustor Monitoring section of this permit shall be met for the
gasoline VCU.
Rule 335-3-16-.05(c)(1)(i)
Subsequent performance testing of the vapor processing system shall
be conducted within twenty-four (24) months of the latest
performance test and once every two (2) years, thereafter to
demonstrate that emissions to the atmosphere from gasoline loading
does not exceed 10 mg of TOC/Liter of gasoline loaded.
Rule 335-3-1-.05
Tests shall be conducted using methods and procedures found
in §60.8 of 40 CFR Subpart A and §60.503(a) of NSPS XX, except
that the 3-run requirement in §60.8 (f) does not apply.
§63.425(a)(1)
§60.503(a)
Immediately before the performance test, the facility, or its
agent, shall check the loading rack for vapor leaks. A leak shall
be defined as a reading of 500 ppm, or greater. All leaks shall
be repaired prior to conducting the test.
§63.425(a)(1)(i)
§60.503(b)
The test shall be conducted during 6-hour period in which the
highest througHPut normally occurs and shall be conducted
according to the requirements specified in §60.503(c)(1) of
NSPS XX.
§63.425(a)(1)
§60.503(c)(1)
The test shall include at least two start-ups and shutdowns of
the vapor processor, which shall be manually controlled, if
necessary, and the vapor holder level shall begin and end at
the same setpoint.
§63.425(a)(1)
§60.503(c)(2)
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During each performance test, the combustor firebox
temperature shall be continuously recorded, and the
minimum firebox temperature setpoint established.
§63.425(a)(1), (b)
Reasons for any changes to firebox temperature since the
previous performance test shall be documented.
§63.425(c)
The emissions rate (E) of total organic compounds during testing shall
be determined using the following equation.
§60.503(3)
=
=n
1i
6
eiesi
10*L
CVK E
where,
E = Emission Rate of Total Organic Compounds in (mg/L
gasoline loaded)
§63.425(a)(1)
§60.503(c)(3)
K = Density of the calibration gas: §63.425(a)(1)
§60.503(c)(3)
For Propane: 1.83 x 106 mg/scm
For Butane: 2.41 x 106 mg/scm
i = emission testing interval of 5-minutes. During each interval,
the following parameters used in the equation are to be
measured:
Vesi = Volume of air-vapor mixture exhausted §63.425(a)(1)
§60.503(c)(4), (5)
Cei = Average Concentration of Total Organic
Compounds
§63.425(a)(1)
§60.503(c)(4), (6)
n = number of testing intervals. This is to be determined by
dividing total time of the test (in minutes), by 5-minutes (the
duration of each interval)
§63.425(a)(1)
§60.503(c)(4)
L = Total volume of gasoline loaded in liters. This is to be
determined using facility records.
§63.425(a)(1)
§60.503(c)(7)
To ensure that cargo tanks meet the vapor-tight requirements, the
facility must follow the procedures specified in §60.502(e)(1)-(5) of
NSPS XX or follow an alternative approved procedures specified in
§60.502(e)(6) of NSPS XX.
Rule 335-3-6-.20(3)(a)
§60.502(e)
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The vapor collection system pressure shall demonstrate compliance
with the gauge pressure requirements under §60.502(h) of NSPS XX as
follows:
§60.502(h)
§60.503(d)
A pressure measurement device (liquid manometer,
magnehelic gauge, or equivalent instrument) used to monitor
the pressure shall be calibrated and installed and shall meet
the requirements specified in §60.503(d)(1) of NSPS XX
§60.503(d)(1)
During performance testing, the following data shall be
recorded:
§60.503(d)(2)
The pressure shall be recorded every five minutes
while a gasoline truck is being loaded
The highest instantaneous pressure that occurs during
each loading shall be recorded
Every loading position must be tested at least once
during the performance test.
Recordkeeping and Reporting Requirements
A record of each visible emission observation conducted on the
gasoline VCU shall be maintained as specified in the chosen method of
monitoring.
Rule 335-3-16-.05(c)(2)
Documents demonstrating that a valid Air Sticker has been obtained
from the Department or from Jefferson County Health Department
shall be maintained.
Rule 335-3-16-.05(c)(2)
Records of H2S content of fuel gas burned in the gasoline VCU shall be
maintained.
[H2S Content (Mole %)]
Rule 335-3-16-.05(c)(2)
§60.48c(f)(4)
§60.105(a)(4)
To demonstrate compliance with NSPS J the following reporting
requirements shall be met:
Rule 335-3-16-.05(a)
An excess emissions report and/or summary report shall be
submitted semi-annually on the following reporting schedule:
Rule 335-3-16-.05(c)(2)
§60.7(c), (d), §60.19(d), (e)
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Reporting Period Submittal Date
January 1 - June 30 August 28
July 1 - December 31 February 28
The excess emission report shall include each rolling 3-hr
period during which the average H2S concentration in the fuel
gas (measured using the continuous H2S monitor) exceeds its
allowable.
§60.105(e)(3)(ii)
The information specified in §60.7(c) of Subpart A and
§60.107(g) of NSPS J shall be provided in each excess emissions
report.
§60.105(e)
§60.107(g)
The following requirements shall be met to demonstrate compliance
with the recordkeeping and reporting requirements under MACT CC
for gasoline loading racks:
§63.650
The applicable recordkeeping and reporting provisions
specified in §63.428(b),(c), (g)(1), (h)(1) through (h)(3), and (k)
of NESHAP R and as summarized in Table 4 of MACT CC shall
be met.
§63.655(b)
§63.428(b),(c), (g)(1), (h)(1)-
(h)(3), (k)
Table 4, MACT CC
(1) A copy of the test results for each gasoline cargo tank
loading at a bulk gasoline terminal shall be maintained
as specified in §63.428(b) of NESHAP R at the terminal,
alternative recordkeeping requirements specified in
§63.428(k) of NESHAP R may be complied with.
§63.428(b)
§63.428(k)
(2) Records of the continuous monitoring data specified in
§63.428(c)(1) of NESHAP R shall be maintained
§63.428(c)(1)
A semi-annual report meeting the following requirement shall
be submitted to demonstrate compliance with MACT CC:
The report shall be submitted on a calendar basis on
the following reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
§63.428(g)
The report shall include each loading of a gasoline
cargo tank for which vapor tightness documentation
had not been previously obtained by the facility.
§63.428(g)(1)
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An excess emissions report and/or summary report shall be
submitted semi-annually on the following reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1 - December 31 February 28
§63.10(e)(3)
§63.428(h)
An excess emissions report shall be submitted to the
Department regardless of whether or not a CMS is
installed
§63.428(h)
The excess emission report shall include each of the
occurrences specified in §63.428(h)(1) through (3) of
NESHAP R.
§63.428(h)(1)-(3)
There are no additional reporting and recordkeeping
requirements for gasoline loading racks under MACT CC unless
a gasoline loading rack is included in an emissions average.
§63.655(b)
Recordkeeping and reporting for emissions averages are
specified in §63.653 and in §63.655(f)(5) and (g)(8) of MACT
CC.
§63.653, §63.655(a)
§63.655(f)(5)
§63.655(g)(8)
Each record shall be maintained in a manner such that they can
be readily accessed within 24 hours and shall be maintained
for a period not less than five years from the date the
information is recorded unless otherwise specified.
§63.10(b)
§63.420(h)
Table 1 of NESHAP R
Each performance test report conducted on the gasoline vapor
recovery unit shall be submitted to the Department within 30 days of
the test date.
Rule 335-3-16-.05(c)(2)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the general proviso subpart
of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
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Summary Page for NESHAP Y and MACT CC: Marine Vessel Loading
Operations
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
MARINE VESSEL LOADING OPERATIONS
EAST DOCK
WEST DOCK
OHAP Maintain tons per year (TPY) of HAPs
and loading througHPut below levels
that would trigger applicability during
marine loading operations
*Existing Source with:
<10 TPY of one HAP
<25 TPY all HAPs
<10 M Barrels of Gasoline per year
<200 M Barrels of Crude Oil per year
§63.651, [MACT CC]
§63.567(j)(4)[NESHAP Y]
§63.560(a)(2), (b)(2)*
[NESHAP Y]
158
Provisos for Summary Page for Marine Vessel Loading Operations
Federally Enforceable Provisos Regulations
Applicability
Each marine vessel loading operation shall be subject to the
requirements specified in ADEM Admin. Code r. 335-3-16, “Major Source
Operating Permits”, and the requirements specified in this subpart of this
permit.
Rule 335-3-16-.03
§63.642(a)
Each marine vessel loading operation shall be subject to the applicable
requirements of 40 CFR 63 Subpart A, “General Provisions” as specified
in the applicable subpart under 40 CFR Part 63 and the requirements
specified in this subpart of this permit.
§63.642(c)
Table 6, MACT CC
§63.560(c)
Table 1, NESHAP Y
Each marine vessel loading operation shall be subject to the
requirements specified in 40 CFR 63 Subpart CC, “National Emission
Standards for Hazardous Air Pollutants (HAPs) from Petroleum
Refineries” [Refinery MACT 1/MACT CC], and the requirements specified
in this subpart of this permit, except as specified in §63.640(d) and (g).
§63.640 (a), (c)(6), (d), (g), (i),
(j), (l)
§63.651
Compliance with MACT CC shall be met by complying with the
applicable requirements specified in §63.560 through §63.568 of
40 CFR 63, Subpart Y, “National Emission Standards For Marine
Tank Vessel Loading Operations” [NESHAP Y] and the
requirements specified in this subpart of this permit.
§63.651
§63.567(b)(1)
63.560(d)(3)
All terms not defined in §63.641 shall have the meaning shall
have the meaning given to them in subpart 40 CFR 63 Subpart A
or in NESHAP Y. The §63.641 definition of “affected source”
applies under MACT CC.
§63.651(b)
The notification reports under §63.567(b) of NESHAP Y are not
required.
§63.651(c)
§63.567(b)
The compliance time of 4 years after promulgation of NESHAP Y
does not apply. The compliance time is specified in
§63.640(h)(1).
§63.640(h)(1)
§63.651(d)
If a flare is used as a control device, the flare shall meet the
requirements of §63.670 of MACT CC.
§63.651(d)
Emission Standards
Existing sources at a major source having aggregate actual HAPs
emissions less than 10 and 25 tons calculated annually from marine tank
vessel loading operations at all loading berths are exempt from the
emissions standards specified in §63.562(b) and (d) of NESHAP Y.
§63.641
§63.560(a)(2),(3)
§63.561
§63.565(l)
159
Provisos for Summary Page for Marine Vessel Loading Operations
Federally Enforceable Provisos Regulations
A source with less than 10 and 25 tons that increase emissions
such that it becomes a source with emissions of 10 or 25 tons
shall comply with the maximum achievable control technology
(MACT) standards in §63.562(b) of NESHAP Y within 3 years
following the exceedance of the threshold level.
§63.561
§63.560(e)(1)(iii)
§63.562(b)
Existing sources with emissions less than 10 and 25 tons shall
comply with the submerged fill requirements specified in
§63.560(a)(4) of NESHAP Y.
§63.641
§63.560(e)(1)(iv)
Existing sources at a major source with a througHPut of less than 10
million (M) barrels of gasoline annually and of less than 200 M barrels of
crude oil annually are exempt from the emissions standards specified in
§63.562(c) and (d) of NESHAP Y.
§63.560(b)(2)
§63.561
A source with a througHPut less than 10 M barrels and 200 M
barrels that increases its througHPut such that it becomes a
source with a througHPut of 10 M barrels or 200 M barrels shall
comply with the reasonably available control technology (RACT)
standards in §63.562(c) of NESHAP Y within 3 years following the
exceedance of the threshold levels. An extension of the
compliance date can be granted as specified in proviso 2(b) of
this section of this subpart.
§63.561
§63.560(e)(2)(iv)
§63.562(c)
Source with througHPut of 10 M barrels or 200 M barrels may
apply for approval from the Department for an extension of the
compliance date of up to 1 year if it is demonstrated that that
the additional time is necessary for installation of the control
device.
§63.561
§63.560(e)(2)(v)
The applicable requirements specified in §63.651 of MACT CC
shall apply at all times.
§63.642(b)
§63.651
At all times, marine vessel loading must be operated and
maintained, including associated air pollution control equipment
and monitoring equipment, in a manner consistent with safety
and good air pollution control practices for minimizing emissions
as specified in §63.642(n).
§63.642(n)
Compliance and Performance Test Methods and Procedures
The emission estimation procedures specified in §63.565(l) shall be used
to determine an annual estimate of HAPs emissions:
§65.565(l)
160
Provisos for Summary Page for Marine Vessel Loading Operations
Federally Enforceable Provisos Regulations
The commodities exempted by §63.560(d) of NESHAP Y from
marine tank vessel loading operations shall not be included in
the annual estimate.
Emission estimates and emission factors shall be based on test
data, or if test data is not available, shall be based on
measurement or estimating techniques generally accepted in
industry practice for operating conditions at the source.
Emission Monitoring
Monitoring would consist of maintaining the records specified in the
recordkeeping and reporting section of this subpart.
Rule 335-3-16-.05(c)(1)(ii)
§63.560(a)(3)
Recordkeeping and Reporting Requirements
The following requirements shall be met to demonstrate compliance
with the recordkeeping and reporting requirements under MACT CC:
The applicable recordkeeping and reporting provisions specified
in §63.567(a) and §63.567(j)(4) of NESHAP Y and as summarized
in Table 5 of MACT CC shall be met.
§63.655(c)
§63.560(a)(3),
§63.567(a), (j)(4)
Table 5, MACT CC
(1) A copy of the emission estimates determined in
§63.565(l) of NESHAP Y shall be maintained.
(2) Records of marine tank vessel loading operation’s actual
througHPuts by commodity shall be maintained onsite.
There are no additional reporting and recordkeeping
requirements for marine vessel loading operations under MACT
CC unless a wastewater stream is included in an emissions
average.
§63.655(c)
Recordkeeping and reporting for emissions averages are
specified in §63.653 and in §63.655(f)(5) and (g)(8) of MACT CC.
§63.653
§63.655(a), §63.655(f)(5)
§63.655(g)(8)
Each record shall be maintained in a readily accessible location
at the facility site for a period not less than five years from the
date the information is recorded unless otherwise specified.
§63.567(j)(4)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso
15(b) and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
161
Summary Page for MACT CC: Heat Exchangers (Cooling Towers)
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD * REGULATIONS
CLOSED-LOOP RECIRCULATION HEAT EXCHANGE SYSTEMS
Individual Sources:
Pre- Black Warrior Expansion Cooling Towers:
Old Coker Cooling Tower
Crude Unit Cooling Tower
Hydrobon Cooling Tower
VOC/OHAP Inlet VOC Concentration
AND
Outlet VOC Concentration
§63.654
Post-Black Warrior Expansion Cooling Towers:
New Coker Cooling Tower
Hydrocracker Cooling Tower
VOC/OHAP Inlet VOC Concentration
AND
Outlet VOC Concentration
§63.654
Particulate Work practice-- Install Drift
Eliminators
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Each Cooling Tower Opacity No more than one 6 min avg>
20%
OR
No 6 min avg. > 40% in any
sixty (60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
162
Provisos for HAPs from Cooling Towers
Federally Enforceable Provisos Regulations
Applicability
The cooling towers shall be subject to the applicable requirements of
ADEM Admin. Code r. 335-3-4-.01, “Visible Emissions”, and the
requirements specified in this subpart of this permit.
Rule 335-3-4-.01
The New Coker Cooling Tower and the Hydrocracker Cooling Towers
shall each have limits in place in order to avoid a review under ADEM
Admin. Code r. 335-3-14-.04, “Air Permits Authorizing Construction in
Clean Air Areas [Prevention of Significant Deterioration (PSD)]", and
are subject to the requirements specified in this subpart of this permit.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Each cooling tower shall be subject to the requirements specified in
ADEM Admin. Code r. 335-3-16, “Major Source Operating Permits”,
and the requirements specified in this subpart of this permit.
Rule 335-3-16-.03
§63.642(a)
Except as specified in §63.640(d) and (g) and §63.654(b) of 40 CFR 63
Subpart CC “National Emission Standards for Hazardous Air Pollutants
(HAPs) from Petroleum Refineries” [Refinery MACT 1/MACT CC], each
heat exchange system (cooling tower) associated with petroleum
refining process units shall be subject to the requirements of MACT CC
and as specified in this subpart of this permit.
§63.640(a)(1), (2)
§63.640(c)(8), (d), (g), (i), (j), (l)
§63.654(a),(b)
Each cooling tower is subject to the applicable requirements of 40 CFR
63 Subpart A, “General Provisions” [Subpart A], as specified in the
applicable subpart under 40 CFR Part 63 and the requirements
specified in this subpart of this permit.
§63.1, §63.642(c)
Table 6, 40 CFR 63 Subpart CC
Emission Standards
Visible emissions from each cooling tower shall meet the opacity
standards specified in proviso 1(a) and (b) of this section of this
subpart.
Rule 335-3-4-.01(a), (b)
The unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 20%, as determined by
a 6-minute average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-minute period,
the unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
The New Coker Cooling Tower and the Hydrocracker Cooling Tower
shall each be equipped with drift eliminators in order to minimize
particulate emissions.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
163
Provisos for HAPs from Cooling Towers
Federally Enforceable Provisos Regulations
To demonstrate compliance with MACT CC, monitoring to identify
leaks of total strippable volatile organic compounds (VOC) for a closed-
loop recirculation heat exchange system as specified in §63.654(c)(1)
shall be met.
§63.654(c)(1)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards shall be determined using
Method 9 or Method 22 of 40 CFR part 60, appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
Drift eliminators shall be maintained according to the test methods
and procedures specified under the manufacturer’s specification.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Determine the total strippable hydrocarbon concentration (in parts per
million by volume (ppmv) as methane) at each monitoring location
using the “Air Stripping Method (Modified El Paso Method) for
Determination of Volatile Organic Compound Emissions from Water
Sources” Revision Number One, dated January 2003, Sampling
Procedures Manual, Appendix P: Cooling Tower Monitoring, prepared
by Texas Commission on Environmental Quality, January 31, 2003
(incorporated by reference—see §63.14) using a flame ionization
detector (FID) analyzer for on-site determination as described in
Section 6.1 of the Modified El Paso Method.
§63.654(c)(3)
Emission Monitoring
Provided that visible emissions, in excess of the opacity standards, are
observed from a cooling tower at any time that the unit is operating, a
visible emission observation shall be conducted utilizing one of the
specified methods.
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
The drift eliminators shall be installed, maintained, and operated in
accordance with the manufacturer’s specifications.
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
To demonstrate compliance with MACT CC, each cooling tower must
comply with the following requirements:
Samples shall be taken and analyzed as specified in
§63.654(c)(1)(i) or (ii) for a closed-loop recirculation heat
exchange system.
§63.654(c)(1)(i) or (ii)
For existing sources, comply with the monitoring frequency
and leak action level specified in provisos 3(b)(1) or (2) of this
section of this permit and the requirement specified in
§63.654(c)(4).
§63.654(c)(4)
164
Provisos for HAPs from Cooling Towers
Federally Enforceable Provisos Regulations
Monitor monthly using a leak action level defined as a
total strippable hydrocarbon concentration (as
methane) in the stripping gas of 6.2 ppmv.
§63.654(c)(4)(i)
Monitor quarterly using a leak action level defined as
a total strippable hydrocarbon concentration (as
methane) in the stripping gas of 3.1 ppmv unless repair
is delayed as specified in §63.654(f). If a repair is
delayed as provided in paragraph (f) of this section,
monitor monthly.
§63.654(c)(4)(ii)
For new sources, comply with the monitoring frequency and
leak action level must be met by conducting monthly
monitoring using a leak action level defined as a total strippable
hydrocarbon concentration (as methane) in the stripping gas of
3.1 ppmv.
§63.654(c)(5)
A leak for a closed-loop recirculation heat exchange system is
detected if a measurement value of the sample taken from a
location specified in Proviso 3(a) of this section equals or exceeds
the leak action levels specified above.
§63.654(c)(6)(ii)
Except as specified in §63.654(e) and (f), if a leak is detected, the
leak must be repaired to reduce the measured concentration to
below the applicable action level as soon as practicable, but no
later than 45 days after identifying the leak, unless the leak is from
a non-HAP source.
§63.654(d), (e), (f)
If the conditions specified in §63.654(f) are met, repair to a
leaking heat exchange may be delayed.
§63.654(f)
Recordkeeping and Reporting Requirements
A record of each visible emission observation conducted on a cooling
tower shall be maintained as specified in the chosen method of
monitoring.
Rule 335-3-16-.05(c)(2)
The following records shall be kept for cooling towers equipped with
drift eliminators:
Rule 335-3-14-.04(9)(b)
[BACT/PSD Limit]
Records of any periods when the drift eliminators were not
maintained and operated in accordance with manufacturer’s
specifications.
The date, time, and description of all maintenance performed
on the drift eliminators.
165
Provisos for HAPs from Cooling Towers
Federally Enforceable Provisos Regulations
To demonstrate compliance with the recordkeeping and reporting
requirements under MACT CC, the following requirements shall be
met:
The recordkeeping requirements shall be met for cooling
towers as follows:
A Notification of Compliance Status records shall be
maintained as specified in §63.655(f)(1)(vi)
§63.655(f)(1)(vi)
The records specified in §63.654(g) must be
maintained to delay the repair of a leaking heat
exchange system
§63.654(g)
Comply with the recordkeeping requirements
specified in §63.655(i)(5).
§63.655(i)(5)
Copies of all applicable reports and records shall be
kept for at least 5 years except as otherwise specified
in §63.655(i).
§63.655(i)
All applicable records shall be maintained in such a
manner that they can be readily accessed within 24
hours.
§63.655(i)
Records may be maintained in hard copy or computer-
readable form including, but not limited to, on paper,
microfilm, computer, flash drive, floppy disk, magnetic
tape, or microfiche.
§63.655(i)
A heat exchange system at an existing source must notify the
Department at least 30 calendar days prior to changing from
one of the monitoring options specified in §63.654(c)(4) to the
other.
§63.655(h)(7)
A Periodic Report meeting the following requirements shall be
met for each cooling tower:
§63.642(f)
§63.655 (e) and (g)
The requirements specified in §63.655(g)(9)(i) through
(v) shall be included in the report.
§63.655(g)(9)
Reports shall be submitted to the Department on a
semi-annual calendar basis according to the following
reporting schedule:
§63.13(f)
§63.642(f)
§63.655(g)
166
Provisos for HAPs from Cooling Towers
Federally Enforceable Provisos Regulations
Reporting Period Submittal Date
January 1-June 30 August 28
July 1- December 31 February 28
A Periodic Report is not required if no events specified in
§63.655(g)(9) occurred during the reporting period.
§63.655(g)
§63.655(g)(9)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the General Provisos subpart
of this permit.
Rule 335-3-16-.05(c)3(ii)
167
Summary Page for MACT CC: Fenceline Monitoring for Benzene Emissions
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
Fenceline monitoring along the facility
property boundary
Benzene (BZ)
Annual average benzene
concentration (Δc) below the
determined action level
§63.658
[MACT CC]
168
Provisos for MACT CC: Fenceline Monitoring for Benzene Emissions Federally Enforceable Provisos Regulations
Applicability
The fenceline monitoring system shall be subject to the requirements
specified in ADEM Admin. Code r. 335-3-16, “Major Source Operating
Permits”, and the requirements specified in this subpart of this permit.
Rule 335-3-16-.03
§63.642(a)
The fenceline monitoring system is subject to the applicable requirements of
40 CFR 63 Subpart A, “General Provisions”, as specified in the applicable
subpart under 40 CFR Part 63 and the requirements specified in this subpart
of this permit.
§63.1
§63.642(c)
Table 6, MACT CC
The fenceline monitoring system shall be subject to the requirements
specified in 40 CFR 63 Subpart, CC “National Emission Standards for
Hazardous Air Pollutants (HAPs) from Petroleum Refineries’, and the
requirements specified in this subpart of this permit.
§63.640(a), §63.658
Emission Standards
The action level for benzene (BZ) is 9 micrograms per cubic meter (µg/m3) on
an annual average basis
§63.658(a)
§63.658(f)(3)
If the annual average benzene concentration (Δc) is less than or equal
to 9 µg/m3, the concentration is below the action level.
If the annual average benzene concentration (Δc) is greater than 9
µg/m3, the concentration is above the action level and a root cause
analysis and corrective action shall be conducted as specified in
§63.658(g). A corrective action plan shall be developed provided
that the conditions specified in §63.654(h) are met.
§63.658(g), (h)
Approval for a site-specific monitoring plan to account for offsite upwind
sources or onsite sources excluded under §63.640(g) may be requested from
the Department according to the requirements specified in §63.658(i)(1)
through (4).
§63.658(i)
Compliance and Performance Test Methods and Procedures
Samples shall be analyzed in accordance with Methods 325A and 325B of 40
CFR 63, Appendix A or an alternative test method may be requested as
specified in §63.658(k).
§63.658(a)
§63.658(k); §63.7(f)
Except as specified in §63.658(c)(1)(i) through (iv), passive monitor
locations shall be determined in accordance with Section 8.2 of Method
325A of 40 CFR 63, Appendix A.
A root cause analysis and corrective action may include, but is not limited to,
the methods and procedures specified in §63.658(g)(1) through (4).
§63.658(g)(1)-(4)
169
Provisos for MACT CC: Fenceline Monitoring for Benzene Emissions Federally Enforceable Provisos Regulations
Emission Monitoring
The following monitoring requirements shall be met for sampling to
demonstrate compliance with MACT CC for fenceline monitoring:
Sampling shall be conducted along the facility property boundary. §63.658(a)
The target analyte is benzene. §63.658(b)
Meteorological data shall be collected and recorded as specified in
§63.658(d).
§63.658(d)
For a root cause analysis, the following requirements shall be met: §63.658(g)
A root cause analysis shall be conducted to determine the cause of
the exceedance and to determine appropriate corrective action
within 5 days of determining that the action level has been exceeded
for any annual average Δc and no longer than 50 days after
completion of the sampling period.
A root cause analysis and initial corrective action analysis shall be
completed, and initial corrective actions taken no later than 45 days
after determining there is an exceedance.
For a corrective action plan, the following requirements shall be met: §63.658(h)
(a) The corrective action plan shall describe the corrective action(s)
completed to date, additional measures proposed to reduce
fenceline concentrations below the action level, and a schedule for
completion of these measures.
(b) The plan shall be submitted to the Department within 60 days after
receiving the analytical results indicating that the Δc value for the 14-
day sampling period following the completion of the initial corrective
action is greater than 9 µg/m3.
if no initial corrective actions were identified, the plan shall be
submitted to the Department no later than 60 days following the
completion of the corrective action analysis required in §63.658(g).
Recordkeeping and Reporting Requirements
The following recordkeeping requirements shall be met for fenceline
monitoring under MACT CC:
§63.655(i)
§63.655(i)(8)
Records, specified in §63.655(i)(8)(i) through (x), shall be kept on an
ongoing basis.
170
Provisos for MACT CC: Fenceline Monitoring for Benzene Emissions Federally Enforceable Provisos Regulations
Copies of all applicable reports and records shall be kept for at least
5 years except as otherwise specified in §63.655(i).
All applicable records shall be maintained in such a manner that they
can be readily accessed within 24 hours.
Records may be maintained in a hard copy or computer-readable
form including, but not limited to, on paper, microfilm, computer,
flash drive, floppy disk, magnetic tape, or microfiche.
The following reporting requirements shall be met for fenceline monitoring
under MACT CC:
§63.642(f), §63.655 (e)(3),
§63.655(h)(8), (10)
§63.658(j)
Table 11, No.4(vi),
Except as specified in §63.655(h)(10), the information specified in
§63.655(h)(8)(i) through (viii) shall be electronically submitted
quarterly to EPA’s Compliance and Emission Data Reporting Interface
(CEDRI) by accessing it through EPA’s Central Data Exchange (CDX)
(htps://cdx.epa.gov/).
Reports shall be submitted electronically on a calendar quarterly
basis according to the following reporting schedule:
Reporting Period Submittal Date
Q1| January 1-March 31 May 15
Q2| April 1- June 30 August 15
Q3| July 1- September 30 November 15
Q4| October 1- December 31 February 15
A notification demonstrating submission of the quarterly report to
EPA along with a summary of the two week sampling Δc and annual
average Δc determined during the reporting period shall be
submitted to the Department on the schedule specified in proviso 2
(b) of this section of this permit.
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
171
Summary Page for NSPS Ja and MACT CC: Delayed Coking Units (DCU)
Process Vents
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
ALL RELEASES ASSOCIATED WITH DECOKING OPERATIONS
OF A DELAYED COKING UNIT
COKE DRUM A
COKE DRUM B
COKE DRUM C
COKE DRUM D
VOC
HAPs
Average vessel pressure
of 2 psig or less
determined on a rolling
60-event average;
Depressure to blowdown
system
§60.103a(i) [NSPS Ja]
§63.640(c)(9)
§63.657(a)(1)(i)
[MACT CC]
172
Provisos for DCU Process Vents
Federally Enforceable Provisos Regulations
Applicability
Each delayed coking unit shall be subject to the requirements specified
in ADEM Admin. Code r. 335-3-16, “Major Source Operating Permits”,
and the requirements specified in this subpart of this permit.
Rule 335-3-16-.03
§63.642(a)
Each delayed coking unit is subject to the applicable requirements of
40 CFR 60 Subpart A, “General Provisions”, as specified in the
applicable subpart under 40 CFR Part 60, and the requirements
specified in this subpart of this permit.
§60.1
Each coke drum vent shall demonstrate compliance with the
requirements of 40 CFR Part 60, Subpart Ja ”Standards of Performance
for Petroleum Refineries” [NSPS Ja] ,and the requirements specified in
this subpart of this permit.
§60.100a(a), (b) and (c)(1)
§63.103a(i)
§63.640(q)
Compliance with this subpart shall be met by complying with
the requirements to send uncondensed vapor to the flare as
specified under the Process Flares and Associated Process Vent
Units subpart of this permit.
§63.670
Compliance with this subpart shall be met by complying with
the pressure requirements specified under 40 CFR 63 Subpart
CC “National Emission Standards for Hazardous Air Pollutants
(HAPs) from Petroleum Refineries” [Refinery MACT 1/MACT
CC], for each delay coking unit and the requirements specified
in this subpart of this permit.
§63.640 (a), (i), (j), (l). (q)
§63.657(a)
Each delayed coking unit is subject to the applicable requirements of
40 CFR 63 Subpart A, “General Provisions”, as specified in the
applicable subpart under 40 CFR Part 63 and the requirements
specified in this subpart of this permit.
§63.1, §63.642(c)
Table 6, 40 CFR 63 Subpart CC
All releases associated with the decoking operations of a delayed
coking unit, as defined in §63.641, shall be subject to the requirements
specified in MACT CC and the requirements specified in this subpart of
this permit.
§63.640(a), (c)(9), (h), (l)
§63.641
§63.657(a)(1)(i)
Table 11 of MACT CC
Emission Standards
To demonstrate compliance with MACT CC for delayed coking units,
the following standards must be met:
§63.640(c)(9)
Prior to venting to atmosphere, draining, or deheading the
coke drum at the end of the cooling cycle, each coke drum shall
§63.642(h)
§63.657(a)(1)(i)
173
Provisos for DCU Process Vents
Federally Enforceable Provisos Regulations
meet an average vessel pressure of 2 psig or less determined
on a rolling 60-event average.
Each coke drum shall be depressurized to a closed blowdown
system until the coke drum vessel pressure meets an average
vessel pressure of 2 psig or less.
§63.642(h)
§63.657(a)(1)(i)
§63.657(d)
The coke drum vessel pressure shall be determined on
a 5-minute rolling average basis while the coke drum
is vented to the closed blowdown system and the last
complete 5-minute rolling average pressure just prior
to initiating steps to isolate the coke drum prior to
venting, draining or deheadings shall be used
determine the average coke drum vessel pressure.
Pressure readings after initiating steps to isolate the
coke drum from the closed blowdown system, just
prior to atmospheric venting, draining, or deheading
the coke drum, shall not be used in determining the
average coke drum vessel pressure.
The applicable requirements specified in §63.657 of MACT CC
shall apply at all times.
§63.642(b)
§63.657
At all times, the delayed coking unit must be operated and
maintained, including associated air pollution control
equipment and monitoring equipment, in a manner consistent
with safety and good air pollution control practices for
minimizing emissions as specified in §63.642(n).
§63.642(n)
Compliance and Performance Test Methods and Procedures
No performance testing requirements apply to delayed coking units. §63.642(d)
Emission Monitoring
To comply with the pressure limits under MACT CC for delayed coking
units, the following requirements shall be met:
§63.657(b)
A monitoring system capable of determine the coke drum
vessel pressure, shall be installed, operated, calibrated, and
maintained
The pressure monitoring system shall be located at the top of
the coke drum or in the overhead line of the coke drum as near
as practical to the coke drum in a representative location that
§63.657(a)(1)(i)
§63.657(b)(1)
174
Provisos for DCU Process Vents
Federally Enforceable Provisos Regulations
minimizes or eliminates pulsating pressure, vibration, and to
the extent practical, internal and external corrosion.
The pressure monitoring system must be capable of measuring
a pressure of 2.0 psig within ± 0.5 psig.
§63.657(b)(2)
To ensure that the pressure monitoring system is functioning as
required under MACT CC, the following requirements shall be met:
The system must be verified annually or at the frequency
recommended by the instrument manufacturer.
§63.657(b)(3)
The system must be verified 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.
§63.657(b)(3)
All components of the system must be visually inspected for
integrity, oxidation and galvanic corrosion every 3 months,
unless the system has a redundant pressure sensor.
§63.657(b)(4)
The output of the system must be reviewed each day the unit
is operated to ensure that the pressure readings fluctuate as
expected between operating and cooling/decoking cycles to
verify the pressure taps are not plugged.
§63.657(b)(5)
Plugged pressure taps must be unplugged or otherwise
repaired prior to the next operating cycle.
§63.657(b)(5)
Recordkeeping and Reporting Requirements
The following requirements shall be met to demonstrate compliance
with the recordkeeping and reporting requirements under MACT CC:
(a) The recordkeeping requirements shall be met for delayed
coking units as follows:
§63.642(e), §63.655(i)
§63.655(i)(7)
Records of the average pressure for the 5-minute
period prior to venting to the atmosphere, draining or
deheading the coke drum for each cooling cycle for
each coke drum shall be maintained.
Records of each 60-cycle rolling average pressure,
considering all coke drum venting events shall be
maintained.
175
Provisos for DCU Process Vents
Federally Enforceable Provisos Regulations
Copies of all applicable reports and records shall be
kept for at least 5 years except as otherwise specified
in §63.655(i).
All applicable records shall be maintained in such a
manner that they can be readily accessed within 24
hours.
Records may be maintained in hard copy or computer-
readable form including, but not limited to, on paper,
microfilm, computer, flash drive, floppy disk, magnetic
tape, or microfiche.
A Periodic Report meeting the following requirements shall be
met for delayed coking units:
§63.642(f)
§63.655 (e) and (g)
The requirements specified in §63.655(g)(12)(i)
through (iii) shall be included in the report.
§63.655(g)(12)
Reports shall be submitted to the Department on a
semi-annual calendar basis according to the following
reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1- December 31 February 28
§§63.13(f)
§63.642(f)
§63.655(g)
A Periodic Report is not required if no events specified
in §63.655(g)(12) occurred during the reporting
period.
§63.655(g)
§63.655(g)(11)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the General Provisos subpart
of this permit.
Rule 335-3-16-.05(c)3(ii)
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177
Summary Page for MACT CC: Miscellaneous Process Vents (Including
Maintenance Vents and Bypass Lines)
Permitted Operating Schedule for
Maintenance Vents:
During startup, shutdown, maintenance, or inspection of
equipment [§63.643(c)]
Permitted Operating Schedule for all other
Miscellaneous Process Vents†:
24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
†Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission limitations:
Emission
Point
Description Pollutant Emission
Limit/Standard
Regulations
Group 1 Miscellaneous Process Vents
(MPV)
HAPs Reduce emissions of organic HAPs using a
flare
§63.643(a)(1)
[MACT CC]
Maintenance Vents HAPs/VOC
Vapor in the equipment served by the vent
has a lower explosive limit (LEL) of less than
10 percent
OR
The pressure in the equipment served by
the vent is reduced to five (5) pounds per
square inch gauge (psig) or less
OR
The equipment served by the vent contains
less than 72 pounds of total VOC
OR
Vents associated with equipment
containing pyrophoric catalyst and no pure
hydrogen supply, the LEL of the vapor must
be less than 20 percent, except for one
event per year not to exceed 35 percent
OR
The pressure in the equipment served by
the vent is reduced to 2 psig or less. Active
purging of the equipment may be used
provided that the equipment pressure at
the location where the purge gas is
introduced remains at 2 psig
§63.643(c)
[MACT CC]
Bypass Lines on Group 1
Miscellaneous Process Vents
HAPs Route vent stream to the flare that meets
the requirement
§63.644(c)
[MACT CC]
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Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
Applicability
Miscellaneous process vents (including maintenance vents) shall be subject
to the requirements specified in ADEM Admin. Code r. 335-3-16-.03, “Major
Source Operating Permits”, and the requirements specified in this subpart
of this permit.
Rule 335-3-16-.03
§63.645(a)
Miscellaneous process vents (including maintenance vents) are subject to
the applicable requirements of 40 CFR 63 Subpart A, “General Provisions”,
as specified in the applicable subpart under 40 CFR Part 63 and the
requirements specified in this subpart of this permit.
§63.1
§63.642(c)
Table 6, 40 CFR 63 Subpart CC
Miscellaneous process vents (including maintenance vents) shall be subject
to the requirements specified in 40 CFR 63 Subpart, CC “National Emission
Standards for Hazardous Air Pollutants (HAPs) from Petroleum Refineries"
[Refinery MACT 1/MACT CC], and the requirements specified in this subpart
of this permit.
§63.640(a), (c)(1),(h)
§63.643(a) and (c)
Group 1 miscellaneous process vents, as defined in §63.641 of MACT CC,
shall be subject to the applicable requirements of 40 CFR 63 subpart G,
“Process vent provisions—performance test methods and procedures to
determine compliance”, by reference in MACT CC.
§63.641
§63.645(a)-(d)
Emission Standards
Group 1 miscellaneous process vents shall reduce emissions of organic
hazardous air pollutants (HAPs) using a flare subject to the requirements of
§63.670 and §63.671 of MACT CC as specified in the Process Flares and
Associated Process Unit Vents subpart of this permit.
§63.641
§63.643(a)(1)
§63.644(c)
§63.670 and §63.671
Provided that the vent system contains bypass lines that could
divert a vent stream away from the control device either directly to
the atmosphere or to a control device that does not comply with
the requirements in §63.643(a) the requirements specified in
§63.644(c)(1),(2), or (3) shall be met.
§63.643(a)
§63.644(c)
A violation is deemed to occur provided a bypass line is used to
divert a Group 1 miscellaneous process vent stream to atmosphere
or to a control device that does not meet the requirements on
§63.643(a).
§63.643(a)
§63.644(c)
A process vent may be designated as a maintenance vent if the vent is only
used as a result of startup, shutdown, maintenance, or inspection of
equipment where equipment is emptied, depressurized, degassed or placed
into service. Process vents designated as maintenance vents must only
comply with the following requirements:
§63.643(c)
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Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
Prior to venting to the atmosphere, the following conditions shall
be met as specified in §63.643(c) of MACT CC:
§63.643(c)
Process liquids shall be removed from the equipment as
much as is practical.
§63.643(c)(1)
Equipment shall be depressured to a control device
meeting the requirements specified in §63.643 (a)(1) for a
flare or §63.643 (a)(2) for a control device other than a
flare, a fuel gas system, or back to the process.
§63.643(a), (c)(1)
Except as specified in proviso 2(b) of this section of this
permit, depressuring shall occur until one of the following
conditions, as applicable, is met:
(i) The vapor in the equipment served by the
maintenance vent has a lower explosive limit (LEL)
of less than 10 percent.
§63.643(c)(1)(i)
(ii) If there is no ability to measure the LEL of the vapor
in the equipment based on the design of the
equipment, the following requirements shall be
met:
§63.643(c)(1)(ii)
(A) The pressure in the equipment served by
the maintenance vent shall be reduced to 5
pounds per square inch gauge (psig) or less.
(B) Upon opening the maintenance vent,
active purging of the equipment cannot be
used until the LEL of the vapors in the
maintenance vent (or inside the equipment
if the maintenance is a hatch or similar type
of opening) is less than 10 percent.
(iii) The equipment served by the maintenance vent
contains less than 72 pounds of total volatile
organic compounds (VOC).
§63.643(c)(1)(iii)
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Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
(iv) If the maintenance vent is associated with
equipment containing pyrophoric catalyst
(e.g. hydrotreaters and hydrocrackers) and a pure
hydrogen supply is not available at the equipment
at the time of the startup, shutdown, maintenance,
or inspection activity, the LEL of the vapor in the
equipment must be less than 20 percent, except for
one event per year not to exceed 35 percent.
§63.643(c)(1)(iv)
If, after applying best practices to isolate and purge equipment
served by a maintenance vent, none of the applicable criterion in
provisos 2(a)(3)(i) through (iv) of this section of the permit can be
met prior to installing or removing a blind flange or similar
equipment blind, the pressure in the equipment served by the
maintenance vent is reduced to 2 psig or less. Active purging of the
equipment may be used provided the equipment pressure at the
location where purge gas is introduced remains at 2 psig or less.
§63.643(c)(1)(v)
At all times any affected source, including associated air pollution control
equipment and monitoring equipment, must be operated and maintained
as follows:
In a manner consistent with safety and good air pollution control
practices for minimizing emissions as specified in §63.642(n) for
each maintenance venting event.
§63.642(n)
§63.643(d)
In a manner consistent with the minimum and/or maximum
operating parameter value or procedure required to be monitored
under §63.644(a) and (b) for Group 1 miscellaneous process vents.
§63.644(a), (b), (e)
Operation of the control device in a manner that constitutes a
period of excess emissions, as defined in §63.655(g)(6), or failure to
perform procedures required shall constitute a violation of the
applicable emission standard of this subpart.
§63.644(e)
§63.655(g)(6)
Compliance and Performance Test Methods and Procedures
Except for maintenance vents complying with the alternative specified in
proviso 2(a)(3)(iii) of the emission standards section of this permit, the
lower explosive limit (LEL) or, if applicable, equipment pressure must be
determined by following the procedures for calibration and maintenance
according to manufacturer’s specification.
§63.643(c)(2)
181
Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
For maintenance vents complying with the alternative in proviso 2(a)(3)(iii)
of the emission standards section of this permit, equipment size may be
determined from equipment design specifications and equipment contents
may be determined using process knowledge.
§63.643(c)(3)
Except as specified in §63.116(a)(1), (d), and (e) of Subpart G and §63.645(b)
through (d) and (i), Group 1 miscellaneous process vents shall demonstrate
compliance with MACT CC by conducting the applicable performance test
methods and procedures specified in §63.116.
§63.116
§63.645
Provided that it is necessary to determine the total organic compound (TOC)
for Group 1 miscellaneous process vents, the applicable methods and
procedures specified in §63.645(e), (f), or (g) shall be met.
§63.645(e), (f), (g)
Whenever process changes, as specified in §63.645(h), are made to
determine whether a vent is Group 1 or Group 2, the TOC emission rate shall
be re-calculated for each Group 2 process vent.
§63.645(h)
Method 22 of 40 CFR 60 Appendix A shall be used to determine visible
emissions.
§63.645(i)
Emission Monitoring
When applicable, the LEL or equipment pressure shall be determined using
process instrumentation or portable measurement devices.
§63.643(c)(2)
When applicable, the mass of VOC in the equipment served by the
maintenance vent shall be determined based on the equipment size and
contents after considering any contents drained or purged from the
equipment.
§63.643(c)(3)
Except that an approval is made as allowed under §63.644(b) to monitor an
alternative parameter other than those specified in §63.644(a), each Group
1 miscellaneous process vent shall vent to a flare that meets the following
requirements:
§63.644(a),(b)
§63.670
The requirements of §63.670 as specified in the emission
monitoring section of the Process Flares and Associated Process
Unit Vents subpart of this permit.
All monitoring equipment shall be installed, calibrated, maintained,
and operated according to manufacturer's specifications or other
written procedures that provide adequate assurance that the
equipment will monitor accurately.
182
Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
A range shall be established that ensures compliance with the emission
standard for each parameter monitored.
§63.644(d)
Provided that a Group 1 miscellaneous process vent using a vent system
contains a bypass line that could divert a vent stream away from a control
device, the requirements specified in §63.644(c) shall be met.
§63.644(c)
To determine whether a miscellaneous process vent from a distillation unit
is subject to the requirements of MACT CC, the procedures specified in
§63.640(f) shall be met.
§63.640(f)
Recordkeeping and Reporting Requirements
The following recordkeeping requirements shall be met to demonstrate
compliance with MACT CC:
§63.643(a), §63.655(i),
§63.655(i)(3), (4), (12)
Records specified in §63.655(i)(3)(i) through (v) shall be maintained
for Group 1 miscellaneous process vents required to continuously
monitor operating parameters.
For each closed vent system that contains bypass lines that could
divert a vent stream shall maintain a record of the information
specified in §63.655(i)(4).
Records specified in §63.655(i)(12)(i) through (vi) shall be kept for
each opening of maintenance vents.
Copies of all applicable reports and records shall be kept for at least
5 years except as otherwise specified in §63.655(i).
All applicable records shall be maintained in such a manner that
they can be readily accessed within 24 hours.
Records may be maintained in a hard copy or computer-readable
form including, but not limited to, on paper, microfilm, computer,
flash drive, floppy disk, magnetic tape, or microfiche.
Records necessary to demonstrate compliance with the
requirements of §63.642(n), including, if appropriate, records of
existing standard site procedures used to deinventory equipment
for safety purposes shall be kept.
§63.643(d)
§63.642(n)
A Periodic Report meeting the following requirements shall be met for
maintenance vents:
§63.643(a)
§63.655(e)(2), (g)(13)
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Summary Page for Miscellaneous Process Vents (Including Maintenance Vents)
Federally Enforceable Provisos Regulations
The information specified in §63.655(g)(13)(i) through (iv) shall be
included for any release exceeding the applicable limits specified in
§63.643(c)(1) for maintenance vents.
§63.643(c)(1)
§63.655(g)(13)
If complying with the standard specified in proviso
2(a)(3)(iv) of the emission standards section of this permit,
each venting event for which the lower explosive limit is 20
percent or greater must be reported.
If complying with the standard specified in in proviso 2(b)
of the emission standards section of this permit, each
venting event conducted under these provisions must be
reported and must include an explanation for each event
and why utilization of this alternative was required.
Subsequent reports shall be submitted on a semi-annual calendar
basis according to the following reporting schedule:
§63.6(i), §63.643(a)
§63.655(f), (g)
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
A Periodic Report is not required if no events specified in §63.655(g)(13)
occurred during the reporting period.
§63.655(g)
The information required in §63.655(f)(3) is required to be maintained in
the Notification of Compliance Status report in order to establish the range
to ensure compliance with the emission standards for each parameter
monitored.
§63.644(d)
§63.655(f)(3)
Provided that a different parameter is monitored other than those specified
in §63.644 the information specified in §63.655(h)(4) shall be submitted.
§63.644
§63.655(h)(4)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
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185
Summary Page for MACT UUU: Bypass Lines for CRU and SRU Vents
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
BYPASS LINES ASSOCIATED WITH THE FOLLOWING UNITS
Sulfur Recovery System No. 1
Sulfur Recovery System No. 2
Platformer No. 1
ISOM Unit
HAPS
WORK PRACTICE
STANDARDS
Vent to a Flare meeting the
requirements of §63.670
and §63.671
OR
Comply with other options
allowed under this subpart
§63.1569(a)(1)(iv)
[MACT UUU]
§63.1569(a)(1) or (2)
Table 36., MACT UUU
CCR Platformer HAPS Install and operate an
electronic valve position
monitor to determine
whether flow is present in
the bypass line.
OR
Comply with other options
allowed under this subpart
§63.1569(a)(1)(i)
[MACT UUU]
§63.1569(a)(1) or (2)
Table 36., MACT UUU
186
Provisos for Bypass Lines for CRU and SRU Vents
Federally Enforceable Provisos Regulations
Applicability
Each bypass line shall be subject to the applicable requirements of ADEM
Admin. Code r. 335-3-16, “Major Source Operating Permits”, and in this
subpart of this permit.
Rule 335-3-16-.03
Each Group 1 miscellaneous process vents (MPV) using a vent system that
contains bypass lines that could divert a vent stream away from a control
devices used to comply with 40 CFR Part 63 Subpart CC, “National Emission
Standards for Hazardous Air Pollutants from Petroleum Refineries”
[Refinery MACT 1/MACT CC] shall met the requirements under §63.644(c)
of MACT CC . No further requirements shall be applicable to those bypass
lines under this subpart of this permit.
§63.643
§63.644(c)
Except as specified §63.1562 (f)(4), each bypass line serving a new, existing,
or reconstructed catalytic reforming unit (CRU) or sulfur recovery unit
(SRU) shall be subject to the requirements specified in 40 CFR Part 63 MACT
UUU, “National Emission Standards for Hazardous Air Pollutants (HAPs) for
Petroleum Refineries” [MACT UUU], and this subpart of this permit.
§63.1560
§63.1561
§63.1562(a), (b)(4), (c)-(e)
§63.1562(f)(4), §63.1563
§63.1569(a)
Each bypass line is subject to the applicable requirements of 40
CFR 63 Subpart A “General Provisions”, as specified in Table 44 of
MACT UUU and in this subpart of this permit.
§63.1577
Table 44, MACT UUU
Nothing in this subpart shall preclude the Permittee from selecting
an alternative method allowed under this subpart, provided that
written notification is first submitted to the Department.
§63.1569(a)(1)(i)-(iv)
§63.1569(a)(2)
Emission Standards
Bypass lines serving the CRU and SRU vents shall be vented to a flare
meeting the requirements specified §63.670 of MACT CC and as specified
in the emissions standards section under the Provisos for Process Flares
and Associate Process Unit Vent subpart of this permit.
§63.670
§63.1569(a)(1)(iv)
Table 36, No. 4, Option 4,
Table 38, No. 1d, Option 4,
MACT UUU
The CCR wash tower vent shall install and operate an electronic valve
position monitor meeting the following work practice standards:
§63.1569(a)(1)(i)
Table 36, No. 1, Option 1,
MACT UUU
The monitor shall either continuously or at least every hour,
determine whether flow is present in the bypass line.
The monitor shall be installed as near as practical to the entrance
to any bypass line that could divert the vent stream away for the
control device to the atmosphere.
187
Provisos for Bypass Lines for CRU and SRU Vents
Federally Enforceable Provisos Regulations
A written operation, maintenance, and monitoring plan shall be developed
and implemented in accordance with §63.1574(f). Each flare and
electronic valve position monitor used to control bypass lines shall be
operated at all times in accordance with the procedures in the plan.
§§63.1569(a)(3), (b)(3), (c)(2)
§63.1574(f)
§63.1576(e)
Each CRU and SRU vent, including air pollution control and monitoring
equipment, shall always be operated and maintained at all times in a
manner consistent with safety and good air pollution control practices for
minimizing emissions as specified in §63.1570(c).
§63.1570(c)
Compliance and Performance Test Methods and Procedures
The methods and procedures specified in §63.670 of MACT CC for flares
and as specified in Proviso 4 of the compliance and performance test
methods and procedures section under the Provisos for Process Flares and
Associate Process Unit Vent subpart of this permit shall be met to
demonstrate compliance with MACT UUU for bypass lines.
§63.670
Continuous compliance with the work practice standards shall be
demonstrated by complying with the procedures in your operations,
maintenance, and monitoring plan.
§63.1569(c)(1)
Emission Monitoring
The flare monitoring requirements specified in §63.671 of MACT CC and as
specified in Proviso 6 and 7 of the emission monitoring section under the
Provisos for Process Flares and Associate Process Unit Vent subpart of this
permit shall be met to demonstrate compliance with MACT UUU for bypass
lines.
§63.671
§63.1569(c)(1)
Table 39, No. 4 Option 4, MACT
UUU
An electronic valve position monitor shall demonstrate compliance as
follows:
§63.1569(c)(1)
Table 39, No. 1 Option 1, MACT
UUU
Monitor and record on a continuous basis or at least every hour
whether flow is present in the bypass line
Visually inspecting the device at least once every hour if the device
is not equipped with a recording system that provides a continuous
record
Record whether the device is operating properly and whether flow
is present in the bypass line.
188
Provisos for Bypass Lines for CRU and SRU Vents
Federally Enforceable Provisos Regulations
Recordkeeping and Reporting Requirements
The following recordkeeping and reporting requirements shall be met to
demonstrate compliance with MACT UUU for bypass lines:
§63.1576
A copy of all notifications and reports submitted per MACT UUU,
including for start-ups, shutdowns, and malfunctions.
§63.1576(a)(1)
§63.1569(b)(2)-(4)
§63.1574(a)(3),(d), (f)
Table 38, No. 1d., MACT UUU
The records specified in §63.1576(a)(2)(i) through (iv) shall be
maintained.
§63.1576(a)(2)
Records specified in §63.1576(b) shall be met, where applicable,
for each CEMS or COMS.
§63.1576(b)
Records of each visible emission observations shall be maintained
as specified in §63.6(h) of Subpart A.
§63.1576(c)
A record of the time and duration of any bypass shall be recorded
and reported.
§63.1569(c)(1)
§63.1576(d)
Table 39, No. 4 Option 4, MACT
UUU
Records of performance tests, performance evaluations, and
opacity and visible emissions observations as specified in
§63.10(b)(2)(viii) of subpart A, where applicable shall be
maintained.
§63.1576(a)(3) & (c)
§63.1576(d)
A current copy of the operations, maintenance, and monitoring
plan shall be maintained onsite and available for inspection.
§63.1576(e)
The recordkeeping and reporting requirements shall be met as
specified in Proviso 4 of the recordkeeping and reporting section
under the Provisos for Process Flares and Associate Process Unit
Vent subpart of this permit to demonstrate compliance with MACT
UUU for bypass lines.
§63.670(p)
Records shall be maintained as follows: §63.10(b)(1)
§63.1576(g)-(i)
In a form suitable and readily available for expeditious review
according to §63.10(b)(1) of Subpart A.
Records must be kept for a period of 5 years following the date of
each occurrence, measurement, maintenance, corrective action,
report, or record.
189
Provisos for Bypass Lines for CRU and SRU Vents
Federally Enforceable Provisos Regulations
Records must be maintained onsite for at least 2 years following
the date of each occurrence, measurement, maintenance,
corrective action, report, or record. Records may be maintained
offsite for the remaining 3 years.
The following reporting requirements shall be met:
A Compliance Report shall include the applicable information
specified in §63.1575(c)(1)-(4), the applicable information
specified in §63.1575(d) or (e) for each deviation from an emission
limitation, and the applicable information in §63.1575(f).
§63.1575(a), (c)-(f)
§63.1570(f)
Table 43, No. 1 MACT UUU
Each report shall identify each incidence of deviation from a permit
term or condition including those that occur during startups,
shutdowns, and malfunctions.
§63.1570(f)
§63.1575(c)(4) or (d)
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the permit
that can be used to determine or indicate compliance, that
identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If there are no deviations events that occurred during the
reporting period, a statement that indicates there were no
deviations from the permit requirements shall be included
in the report.
Each report shall be submitted semi-annually on the following
reporting schedule:
Reporting Period Submittal Date
January 1 - June 30 August 28
July 1 - December 31 February 28
§63.1575(b)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
190
[THIS PAGE LEFT BLANK INTENTIIONALLY]
191
Summary Page for MACT UUU: Catalytic Reforming Unit (CRU) Vents
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
CATALTYIC REFORMING UNITS (CRU) VENTS
Platformer No. 1 & ISOM Unit
[Semi-Regenerative CRU]:
During blow down TOC Burn in flare meeting the
requirements of §63.670
§63.1566(a)(1)(i)
Table 15, Option 1
During coke burn-off and rejuvenation HCl Reduce by 92% by weight OR
reduce to a concentration of
30 ppmv (dry) @ 3% O2
§63.1567(a)(1)(i)
Table 22, No. 1
Continuous Catalytic Reformer (CCR) Platformer
[Continuous CRU]
During blow down TOC Burn in fuel gas system or Burn
in flare meeting the
requirements of §63.670
§63.1562(f)(5)
Table 15, Option 1
During coke burn-off and rejuvenation HCl Reduce by 97% by weight OR
reduce to a concentration of
10 ppmv (dry) @ 3% O2
§63.1567(a)(1)(i)
Table 22, No. 3
192
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
Applicability
Each catalytic reforming unit (CRU) vent shall be subject to the
requirements specified in ADEM Admin. Code r. 335-3-16, “Major Source
Operating Permits”, and the requirements specified in this subpart of this
permit.
Rule 335-3-16-.03
Each CRU vent shall be subject to the requirements of 40 CFR 63, Subpart
UUU, “ National Emission Standards for Hazardous Air Pollutants (HAP) for
Petroleum Refineries” [Refinery MACT 2/MACT UUU] for catalytic
reforming units and the requirements specified in this subpart of this
permit.
§63.1560, §63.1561
§63.1562(a), (b)(2), (c)-(e)
§63.1579
The applicable requirements specified in 40 CFR 63, Subpart A,
“General Provisions” [Subpart A], and this subpart of this permit
shall be met as specified in Table 44 of MACT UUU.
§63.1577
Table 44, MACT UUU
A flare used to demonstrate compliance with the requirement of
MACT UUU shall comply with the requirements for a flare as
specified in §63.670 of 40 CFR 63 Subpart CC, “National Emission
Standards for Hazardous Air Pollutants (HAPs) from Petroleum
Refineries” [Refinery MACT 1/MACT CC], instead of the
requirements in §63.11(b) of Subpart A.
§63.1562(f)(5)
§63.1566(a)(1)(i)
Nothing in this subpart shall preclude the Permittee from selecting
an alternative method of compliance under MACT UUU, provided
that written notification is first submitted to the Department.
§63.1566
§63.1567
Emission Standards
Except as specified in §63.1566(a)(4), during initial catalyst depressurizing
and purging operations of organic hazardous air pollutants (OHAP) and
while the reactor pressure is greater than five (5) pounds per square inch
gauge (psig), the following emission limits shall be met:
§§63.1566(a)(3),(4)
The ISOM Unit vent and the No. 1 Platformer vent shall be routed
to a flare that meets the requirements specified in §63.670 of
MACT CC.
§63.1566(a)(1)(i)
Table No. 15 and No.16, Option
1
The CCR Platformer vent shall be routed to the fuel gas system.
Provided that a flare receives gas from the fuel gas system, the
flare must meet the requirements of §63.670 of MACT CC.
§63.1562(f)(5)
§63.670 of MACT CC
193
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
During coke burn-off and catalyst rejuvenation operations, each CRU vent
shall meet the following requirements:
(a) The ISOM Unit and Platformer No. 1 shall vent emissions to a
control device that meets the requirement specified in either
proviso 2(a)(1) or (2) of this section of this subpart.
§63.1567(a)(1)
Table No. 22, No. 1
Reduces hydrogen chloride (HCl) emissions by 92% by
weight
§63.1567(a)(1)(i)
Reduces the HCl concentration to 30 part per million
volume (ppmv) (dry basis) or less corrected to 3% oxygen
(O2)
§63.1567(a)(1)(ii)
The CCR Platformer shall vent emissions to a control device that
meets the requirement specified in either proviso 2(b)(1) or (2) of
this section of this subpart.
§63.1567(a)(1)
Table No. 22, No. 2
Reduces HCl emissions by 97% by weight. §63.1567(a)(1)(i)
Reduces the HCl concentration to 10 ppmv (dry basis) or
less corrected to 3% O2
§63.1567(a)(1)(ii)
Each CRU vent shall be equipped with an internal scrubbing system
that meets one of the following requirements:
§63.1567(a)(2)
The outlet concentration by maintaining the daily average
HCl concentration in the catalyst regenerator exhaust gas
below the limit established during performance testing.
Table No. 23, No. 2
The HCl percent reduction standard by ensuring that the
daily average pH or alkalinity of the water (or scrubbing
liquid) exiting the internal scrubbing system does not fall
below the limit established during the performance test;
and the daily average liquid-to-gas ratio does not fall
below the limit established during the performance test.
Table No. 23, No. 3
A written operation, maintenance, and monitoring plan shall be developed
and implemented in accordance with §63.1574(f). Each CRU vent shall be
operated at all times in accordance with the procedures in the plan.
§§63.1566(a)(5), (c)(2),(b)(7)
§§63.1567(a)(3), (c)(2)
§63.1574(f), §63.1576(e)
Each CRU vent, including air pollution control and monitoring equipment,
shall always be operated and maintained at all times in a manner
consistent with safety and good air pollution control practices for
minimizing emissions as specified in §63.1570(c).
§63.1570(c)
194
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
Compliance and Performance Test Methods and Procedures
A visible emission observation shall be conducted on a flare used to control
emissions from organic HAPS during initial catalyst depressuring and
catalyst purging operations in accordance with Method 22 of 40 CFR Part
60, Appendix A and §63.760 and §63.671 of MACT CC.
§63.1566(b)(2) and (3)
§63.1571
Table 18, Option 1(a)
§63.670 and §63.671, MACT CC
The following methods and procedures shall be followed to conduct
performance testing on each CRU vent during coke burn-off and catalyst
rejuvenation to determine inorganic HAPs emissions from an internal
scrubbing system meeting the HCl outlet concentration limit:
§§63.1567(b)(2), (3)
Table No. 25, No. 1 & 2
§63.1571(a) and b)(1)
Method 1 OR 1A of 40 CFR 60 Appendix A shall be used to
determine the sampling point
Table No. 25, No. 1(a)(2)
Method 2, 2A, 2C, 2D, 2F, OR 2G of 40 CFR 60 Appendix A shall be
used to determine the exhaust gas velocity and volumetric
flowrate
Table No. 25, No. 1(b)
Method 3, 3A OR Method 3B of 40 CFR 60 Appendix A shall be used
to determine the exhaust gas molecular weight
Table No. 25, No. 1(c)
Method 4 of 40 CFR 60 Appendix A shall be used to determine the
exhaust gas moisture content
Table No. 25, No. 1(d)
Method 26A of 40 CFR 60 Appendix A shall be used to determine
the HCl concentration in the exhaust gas
§63.1567(b)(5)
Table No. 25, No. 1(e)
Table No. 26, No. 1 & 2
Emission Monitoring
To control organic HAP emissions from a CRU vent during initial catalyst
depressuring and catalyst purging operations, the following requirements
shall be met to demonstrate initial and continuous compliance with MACT
UUU:
§63.1566(b)
§63.1566(c)(1)
For a flare used as the control device the following monitoring shall
be met:
Emissions shall be vented from the process unit to a flare
meeting the requirements of §63.670 and §63.671 of
MACT CC.
Table 20, Option 1
§63.670 and §63.671, MACT CC
The requirements specified in §63.1566(b) and §63.1571
of MACT UUU shall be met to demonstrate compliance.
Table 18, Option 1(a) and (b)
§63.1566(b)(1)
195
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
A monitoring system that meets the requirements
specified in §63.1572(c) shall be installed, operated,
calibrated, and maintained as specified in §63.670 and
§63.671 of MACT CC.
§63.1566(b)(1)
§63.1572(c), (d)
§63.670 and §63.671, MACT CC
Table 15, 16, 17, 20 Option 1,
MACT UUU
The flare pilot light must be present at all times and the
flare must be operated at all times that emissions may be
vented to it.
§63.1566(c)(1)
Table 21 Option 1, MACT UUU
Performance testing for a flare used to control the CRU vent
emissions shall be conducted on Platformer No. 1, the ISOM Unit,
and the CCR Platformer (when emissions are vented to the flare)
by meeting the following requirements:
§63.1566(b)(2), (3),(5)(i), (6)
§63.1566(c)(2)
§63.1571
Table 18 and 19, Option 1,
MACT CC
(1) For initial compliance using a flare demonstrating
compliance with §63.670 and §63.671 of MACT CC.
Table 18, Option 1
§63.670 and §63.671, MACT CC
(i) Conduct a visible emission observation covering
two consecutive hours
§63.1566(b)(2) & (3)
Table 18, Option 1(a)
(ii) Determine that the flare meets the requirements
for the net heating value of the gas being
combusted and exit velocity
§63.1566(b)(2) & (3)
Table 18, Option 1(b)
(iii) Maintain visible emissions at less than 5-minutes
during any consecutive 2-hour period
Table 19, Option 1
§63.1566(b)(6)
Continuous compliance shall be met by complying with the
procedures in the operation, maintenance, and
monitoring plan.
§63.1566(c)(2)
To control inorganic HAP emission during coke burn-off and catalyst
rejuvenation, the following requirements shall be met to demonstrate
initial and continuous compliance with MACT UUU:
§63.1567(b)
For an internal scrubber used as the control device to meet the HCl
outlet concentration from a CRU, the following monitoring shall be
met:
§63.1567(a)(2)
Table 23, No. 2
Periodic checks shall be conducted using a colormetric
tube sampling system to measure the HCl concentration in
the catalyst regenerator exhaust gas.
§63.1567(b)(1)
§63.1572(c), (d)
Table 24, Option 2
196
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
The colormetric tube sampling system must use a printed
numerical scale in ppmv, a standard measurement range
of 1 to 10 ppmv (or 1 to 30 ppmv if applicable), and a
standard deviation for measured values of no more than
±15 percent. System must include a gas detection pump
and hot air probe if needed for the measurement range.
§63.1567(c)(1)
Table No. 25, No. 3
Table 41, No. 3
The daily average HCl concentration in the catalyst
regenerator exhaust gas must not exceed the limit
established during the performance test.
§63.1567(a)(2), (b)(3)
Table 23, Option 2
Continuous compliance shall be met by maintaining the HCl
concentration below the designated emissions limit.
Table 27, No. 1 & 2
Performance testing for an internal scrubber used to control the
CRU vent emissions from each CRU shall be conducted by meeting
the following requirements:
§63.1567(b)(2)
§63.1571(b)(1)
Table 25, No. 1 & 3
Each test shall consist of three separate test runs of at least
1 hour in duration each as specified in §63.7(3) of Subpart
A.
§63.1571(b)(2)
A performance evaluation must be conducted according
§63.8(e) of subpart A.
§63.1571(b)(3)
Equation 1 and Equation 4 in §63.1567(b)(4) shall be used
to demonstrate initial compliance with the emission limit.
§63.1567(b)(4)(i), (iii)
Data from the colorimetric tubes shall be used to establish
the HCl concentration operating limit as specified in Table
25, No. 3 of MACT UUU. Requirements for colormetric
tubes are detailed in Table No. 41, No. 3 of MACT UUU.
§63.1567(b)(3)
§63.1572(c)
Table No. 25, No. 1 & 3
Table No. 41, No.3
Performance testing must be conducted once every five
years.
Rule 335-3-16-.05(c)(1)(ii)
§63.1567(c)(1)
Table 27, No. 1 & 3
Performance test results shall be submitted to the
Department within 60 days after completing the
performance test.
§63.1575(k)(1)(ii) & (2)
§63.1576(f)(1)
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (f) of this
section of this subpart shall be maintained and made available for
inspection.
§§63.1576(a),(b), (d),(g)-(I)
197
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
Date, starting time, and duration of each deviation from the
requirements specified in this subpart along with the cause and
corrective actions taken
§63.1570(f)
§63.1572(d)
Date, starting time, and duration of each catalyst regeneration
event
§63.1567(c)(2)
Date, time, and results of each visual emission observation §63.1576(a)(3) & (c)
Record of the 4-hour HCl concentrations from each CRU vent §63.1567(c)(1)
The continuous parameter monitoring system (CPMS) records
and/or monthly visible inspection records for each vent
§63.1566(a)(1)
§63.1576(b) & (d)
A copy of all notifications and reports submitted per MACT UUU,
including for start-ups, shutdowns, and malfunctions
§63.1576(a)(1) & (a)(2)
Records shall be maintained as follows: §63.10(b)(1), §63.1576(g)-(i)
In a form suitable and readily available for expeditious review
according to §63.10(b)(1) of Subpart A
Must be kept for a period of 5 years following the date of each
occurrence, measurement, maintenance, corrective action, report,
or record
Must be maintained onsite for at least 2 years following the date
of each occurrence, measurement, maintenance, corrective
action, report, or record. Records may be maintained offsite for
the remaining 3 years
The following reports shall be submitted to demonstrate compliance with
MACT UUU
§63.1575(a), (g)
Table 43, No. 1, MACT UUU
A Compliance Report shall include the applicable information
specified in §63.1575(c)(1)-(4), the applicable information
specified in §63.1575(d) or (e) for each deviation from an emission
limitation, and the applicable information in §63.1575(f)
§63.1575(c)-(f)
Table 43, No. 1, MACT UUU
Each report shall identify each incidence of deviation from a permit
term or condition including those that occur during startups,
shutdowns, and malfunctions.
§63.1570(f)
§63.1575(c)(4) or (d)
198
Provisos for Catalytic Reforming Unit (CRU) Vents
Federally Enforceable Provisos Regulations
If there are no deviations from any emission limitation or
work practice standard that applies to you, a statement
that there were no deviations from the standards during
the reporting period and that no continuous opacity
monitoring system or continuous emission monitoring
system was inoperative, inactive, out-of-control, repaired,
or adjusted.
If you have a deviation from any emission limitation or
work practice standard during the reporting period, the
report must contain the information in §63.1575(c)
through (e).
Each report shall cover a semi-annual reporting period and shall be
submitted according to the following reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1- December 31 February 28
§63.1575(b)
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the General Provisos subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
199
Summary Page for NSPS J and MACT UUU: Sulfur Recovery Systems &
Thermal Oxidizers
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
SULFUR RECOVERY SYSTEMS
Each with:
Claus Sulfur Recovery Unit
Tailgas Treating Unit
Thermal Oxidizer
Oxygen Enrichment
Each Assist Gas Content /Fuel gas H2S ≤ 0.10 gr/dscf (~162 ppmv) §60.104(a)(1)
[NSPS J]
Each Process Gas Streams H2S Gas stream must be burned
to maintain offsite
concentration to 20 ppbv of
H2S in ambient air
Rule 335-3-5-.03(1) and
(2)
Each Thermal Oxidizer Opacity No more than one 6 min
avg> 20%
OR
No 6 min avg. > 40% in any
sixty (60) minute period
Rule 335-3-4.-01(1)(a)
Rule 335-3-4-.01(1)(b)
100 LTon/Day Sulfur Recovery System No. 1:
D10.0801 12.2 MMBTU/Hr Thermal Oxidizer SO2 250 ppmv @ 0% excess air
averaged over a 12-hour
period
§60.104(a)(2)
§63.1568(a)(1)(i)
[MACT UUU]
80 LTon/Day Sulfur Recovery System No. 2
M.1801 6.5 MMBTU/Hr Thermal Oxidizer
w/ Oxygen enrichment
NOX 0.8 Lbs/Hour Rule 335-3-14-.04
[Anti-PSD Limit]
Particulate 2.0 Lbs/Hour Rule 335-3-14-.04
[Anti-PSD Limit]
SO2 250 ppmv @ 0% excess air
averaged over a 12-hour
period
AND
150 ppm averaged over a
365-Consecutive Day period
§60.104(a)(2)
§60.105(e)(4)
§63.1568(a)(1)(i)
[MACT UUU]
Rule 335-3-14-.04
[Anti-PSD Limit]
200
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
Applicability
Each thermal oxidizer shall be subject to the requirements of ADEM
Admin. Code r. 335-3-4-.01, “Visible Emissions”, and this subpart of this
permit.
Rule 335-3-4-.01(1)
The refinery handles gas or refinery gas that contains more than 0.10
grains of hydrogen sulfide (H2S) per standard cubic foot (scf); therefore,
the thermal oxidizers will be subject to the requirements of ADEM
Admin. Code r. 335-3-5-.03, “Petroleum Production”, and this subpart of
this permit.
Rule 335-3-5-.03(2)
Each sulfur recovery plant (SRP) with a thermal oxidizer shall be subject
to the requirements specified in ADEM Admin. Code r. 335-3-16, “Major
Source Operating Permits”, and in this subpart of this permit.
Rule 335-3-16-.03
Thermal oxidizer No. M.1801 has enforceable particulate, sulfur dioxide
(SO2), and nitrogen oxide (NOX) limits in place in order to prevent it from
being subject to the provisions of ADEM Admin. Code Rule 335-3-14-.04,
“Air Permits Authorizing Construction in Clean Air Areas” [Prevention of
Significant Deterioration (PSD)] as specified in this subpart of this
permit.
Rule 335-14-.04
[Anti-PSD Limit]
Each SRP system (as defined in §60.101) and each thermal oxidizer is
subject to the requirements found in 40 CFR Part 60, Subpart J,
”Standards of Performance for Petroleum Refineries” [NSPS J] and in this
subpart of this permit.
§60.100(a) & (b)
§60.101
Rule 335-3-16-.05(a)
Each thermal oxidizer shall be subject to the fuel gas
combustion device requirements specified in NSPS J.
§60.100(a) & (b)
§60.101
The applicable requirements of 40 CFR 60, Subpart A “General
Provisions” shall be met as specified in NSPS J.
40 CFR 60, Subpart A
Rule 335-3-16-.05(a)
Except as specified in §63.1562(f)(2) and (3), process vents or group of
process vents on sulfur recovery units (SRU) or tail gas treatment units
(TGU) serving a sulfur recovery plant (SRP), shall be subject to the
requirements of 40 CFR 63 Subpart UUU, “National Emission Standards
for Hazardous Air Pollutants (HAPs) for Petroleum Refineries” [MACT
UUU] and to this subpart of this permit.
§63.1560, §63.1561(a)
§§63.1562(a), (b)(3), (c), (d),
(f)(2)-(3)
§63.1568, §63.1579
§64.2(b)(1)(i)
The emissions limits specified in §60.104(a)(2)(i) of NSPS J may
be used to demonstrate compliance with MACT UUU.
§60.104(a)(2)(i)
§63.1568(a)(1)(i)
Table 29, No. 1 of MACT UUU
201
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
The applicable requirements of 40 CFR 63, Subpart A “General
Provisions” shall be met as specified in Table 44 of MACT UUU.
§63.1577
Per §63.2(b)(1)(i), the sulfur recovery units would be exempt
from the requirements of 40 CFR 64, “Compliance Assurance
Monitoring” [CAM}. Compliance with MACT UUU shall meet the
requirements CAM.
§63.2(b)(1)(i)
Nothing in this subpart shall preclude the Permittee from
selecting an alternative method of compliance under MACT
UUU, provided that written notification is first submitted to the
Department.
§63.1568
The thermal oxidizer is subject to the monitoring requirements under
CAM as indicated in Proviso 33 of the General Permit Provisos subpart
and in this subpart of this permit.
40 CFR 64
The following definitions shall apply for this subpart: Rule 335-3-16-.05(a)
“Acid Gas” shall mean any gas that contains hydrogen sulfide
and is generated at a refinery by the regeneration of an amine
scrubber solution.
“Sour Water Stripper Gas [SWS Gas]” shall mean the gas
produced by the process of stripping refinery sour water.
“Tail Gas Incident” shall mean the combustion of tail gas in a
thermal that result in excess emissions of 500 pounds, or more,
of sulfur dioxide in any 24-hour period. Only those time periods
having sulfur dioxide concentrations in excess of 250 ppm (1-
hour block average) shall be used to determine the amount of
excess sulfur dioxide emissions from the incinerator. The
Permitee shall use engineering judgment and monitoring data
during periods in which the sulfur dioxide emission analyzer
exceeds the range of the instrument or is out of service.
Emission Standards
Visible emissions from each thermal oxidizer shall meet the opacity
standards specified in proviso 1(a) and (b) of this section of this subpart.
The unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 20%, as determined by a
6-minute average.
Rule 335-3-4-.01(1)(a)
202
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
Except for one 6-minute period during any 60-minute period,
the unit shall not discharge into the atmosphere particulate that
results in an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
All process gas streams containing 0.10 of a grain of hydrogen sulfide
(H2S) per scf shall be burned to the extent that the ground level
concentrations of H2S shall be less than twenty (20) parts per billion
beyond plant property limit, averaged over a thirty (30) minute period.
Rule 335-3-5-.03(2)
The following emission and operational limits shall apply to the Sulfur
Recovery Systems:
Sulfur Recovery System No. 1 and Thermal Oxidizer No.
D10.0801 shall not emit greater than 250 ppmv SO2 at 0% excess
air based on a rolling 12-hour average.
§60.104(a)(2)(i)
§63.1568(a)(1)(i)
Table No. 29, Item 1a, MACT
UUU
§63.1570(a)
Sulfur Recovery System No. 2 and Thermal Oxidizer No. M.1801
shall not emit greater than:
NOX emissions of 0.8 pounds per hour (Lb/hr) Rule 335-3-14-.04
[Anti-PSD Limit]
Particulate emissions of 2.0 Lb/hr Rule 335-3-14-.04
[Anti-PSD Limit]
SO2 emissions of:
(i) 250 ppmv SO2 at 0% excess air based on a
rolling 12-hour average
AND
§60.104(a)(2)(i)
§63.1568(a)(1)(i)
Table No. 29, Item 1a, MACT
UUUU
§63.1570(a)
(ii) 150 ppmv based on a rolling 365-day average Rule 335-3-14-.04
[Anti-PSD Limit]
Sulfur pit emissions shall be routed so that they are eliminated,
controlled, or included and monitored as part of the Sulfur
Recovery Plant’s 250 ppmv/rolling 12-hour average
Rule 335-3-16-.05(a)
To demonstrate compliance with NSPS J, any assist fuel gas that contains
H2S in excess of 0.10 grains per standard cubic feet (gr/scf) (~162 ppmv)
shall not be burned in the thermal oxidizers.
§60.104(a)(1)
203
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
To demonstrate compliance with MACT UUU during periods of startup
and shutdown, the thermal oxidizer shall be operated such that the
following requirements are met when purge gas is routed to it:
§63.1568(a)(4)(iii)
At a minimum the hourly average temperature of 1200 degrees
Fahrenheit (oF) in the firebox is maintained,
AND
A minimum hourly average outlet oxygen (O2) concentration of
2 volume percent (dry basis)
A written operation, maintenance, and monitoring plan shall be
developed and implemented in accordance with §63.1574(f). Each
sulfur recovery plant and thermal oxidizer shall be operated at all times
in accordance with the procedures in the plan.
§§63.1568(a)(3), (b)(6), (c)(2)
§63.1574(f)
§63.1576(e)
Enhanced maintenance and operation of the sulfur recovery plant (SRP)
and the appropriate upstream process units shall be included in a
Preventive Maintenance and Operation Plan (PMO Plan).
Rule 335-3-16-.05(a)
§63.1570(c)
The PMO Plan shall be a compilation of approaches for
exercising good air pollution control practices and for
minimizing SO2 emissions from sulfur processing and other
production processes at the refinery.
The PMO Plan shall have as its goal the elimination of acid gas
flaring and operation of the SRP between scheduled
maintenance turnarounds with minimization of emissions.
The PMO shall be implemented at all times, including periods of
startup, shutdown, and malfunction of the SRP.
A root cause analysis and corrective action analysis shall be conducted
for each Tail Gas Incident if the sulfur dioxide (SO2) emissions discharged
to atmosphere is 500 pounds or greater in a 24-hour period.
Rule 335-3-16-.05(a)
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards for the thermal oxidizer shall be
determined using Method 9, Method 22 of 40 CFR Part 60, Appendix A,
or other methods approved by the Department.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
The following methods and procedures shall be met to conduct
performance testing to determine NOX emissions from the M.1801
thermal oxidizer:
Rule 335-14-.04
[Anti-PSD Limit]
204
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
Method 1 OR 1A of 40 CFR Part 60, Appendix A to determine the
sample and velocity tranverses
Method 2, 2A, 2B, 2C, 2D, OR 2E of 40 CFR Part 60, Appendix A
to determine the velocity and volumetric flow rate
Method 3 OR 3A of 40 CFR Part 60, Appendix A to determine the
gas analysis
Method 4 of 40 CFR Part 60, Appendix A to determine the
moisture in the stack gas
Method 7E of 40 CFR Part 60, Appendix A to determine NOX
emissions
The following methods and procedures shall be met to demonstrate
compliance with performance test requirements in NSPS J for the
thermal oxidizers.
The H2S emission limit shall be determined using the following
method and procedures specified in Method 11, 15, OR 15A of
Appendix A-5 to part 60, OR Method 16 of Appendix A-16- to
part 60, as required in §60.106(e)(1).
§60.105(a)(4)(iii)
§§60.106(a), (e)(1)
Performance evaluations for each H2S monitor shall be
conducted according to the requirements of §60.13(c) of
Subpart A and Performance Specification (PS) 7 of Appendix B,
Part 60.
§60.105(a)(4)(iii)
Relative accuracy evaluations shall be conducted using the
methods and procedures specified in Proviso 3(a) of this section
of the permit.
§60.105(a)(4)(iii)
The following methods and procedures shall be met to demonstrate
compliance with performance test requirements in NSPS J for the sulfur
recovery plants:
Compliance with the SO2 emission limit and O2 concentration
shall be determined using the following methods and
procedures:
§60.106(f)
Table 40, No. 5, MACT UUU
Method 6 OR 6C of 40 CFR Part 60, Appendix A to determine the
SO2 concentration
§60.106(f)(1)
Method 4 of 40 CFR Part 60, Appendix A to determine the
moisture content of the gas
§60.106(f)(1)
205
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
Method 15 of 40 CFR Part 60, Appendix A to determine the H2S
concentration
§60.106(f)(2)
Method 3 OR 3A of 40 CFR Part 60, Appendix A to determine the
oxygen concentration used to correct the emission rate for
excess air
§60.106(f)(3)
Performance evaluations for each SO2 monitor shall be
conducted according to the requirements of §60.13(c) and PS 2
of Appendix B, Part 60,
§60.105(a)(5)(ii)
Emission Monitoring
Provided that visible emissions, in excess of the opacity standards, are
observed from the thermal oxidizer at any time that the unit is
operating, a visible emission observation shall be conducted.
Rule 335-3-4-.01(2)
Rule 335-3-16-.05(c)(1)(i)
The fuel gas assist shall be monitored as specified in the Process Heaters
and Boiler subpart of this permit.
Rule 335-3-16-.05(c)(1)(i)
CAM requirements for each thermal oxidizer shall be met as specified in
Appendix C: Sulfur Recovery Systems’ Thermal Oxidizer of this permit
shall be met to demonstrate that the H2S offsite concentration
requirement is being met.
Rule 335-3-5-.03(2)
§64.3
§64.6(b)
A compliance test for NOX emissions from Sulfur Recovery System No. 2
shall meet the following requirements:
Rule 335-3-16-.05(c)(1)(i)
Shall be conducted once every five (5) years
Shall consist of three runs of at least 1-hour in duration each
This test may be conducted at the same time as the annual SO2
compliance test.
An instrument to continuously monitor and record the concentration by
volume (dry basis) of H2S in the fuel gas before being burned in the
thermal oxidizer shall be installed, operated, calibrated, and
maintained.
§60.105(a)(4)
The span value for the instrument is 425 mg/dscf H2S. §60.105(a)(4)(i)
An exemption from H2S monitoring may be requested for low-
sulfur fuel gas streams by meeting the requirements specified
in §60.105(a)(4)(iv).
§60.105(a)(4)(iv)
§60.105(b)
206
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
A common source of fuel gas may be monitored at only one
location if monitoring at this location accurately represents the
concentration of H2S in the fuel gas being burned in the
respective thermal oxidizer.
§60.105(a)(4)(ii)
To determine the H2S concentration, the monitoring
requirements in §60.106(e)(1)(i)-(iii) shall be met.
§60.106(e)(1)
H2S samples shall be corrected to 0% excess air using the
equation found in §60.106(h)(6).
§60.106(h)(6)
Emission monitoring for the sulfur recovery plants shall be met as
follows:
§60.105(a)(5)
An instrument for continuously monitoring and recording the
concentration (dry basis, zero percent (0%) excess air) of any
SO2 emissions into the atmosphere shall be installed, operated,
calibrated, and maintained. The monitor shall include an
oxygen monitor for correcting the data for excess air.
§60.105(a)(5)
§63.1568(b)(1)
§63.1572(a), (d)
Table 31, No. 1a, MACT UUU
Table 40, No. 5, MACT UUU
A SO2 CEMS and an O2 monitor shall be installed, operated, and
maintained.
§63.1568(b)(5)
§63.1572(a)(1)
Table 33, No. 1a, MACT UUU
The span value is 500 ppm for the SO2 monitor and 25 percent
for the O2 monitor.
§60.105(a)(5)(i)
Table 40, Item Nos.5 & 9, MACT
UUU
The applicable monitoring requirements specified in
§60.106(f)(1)-(3) shall be met.
§60.106(f)
SO2 samples shall be corrected to 0% excess air using the
equation found in §60.106(h)(6).
§60.106(h)(6)
The following data shall be collected to determine continuous
compliance with the emission limit:
§63.1568(c)(1)
Table 34, No. 1a, MACT UUU
Table 35, No. 5a & b, MACT
UUU The hourly average SO2 monitoring data (dry basis,
percent excess air)
Each 12-hr rolling average concentration of SO2 shall be
determined and recorded
Each 12-hour rolling average concentration of SO2 at or
below 250 ppmv at 0% excess air (dry basis) shall be
maintained
207
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
Continuous (at least once every 15 minutes) and hourly
average temperature monitoring data shall be collected
according to §63.1572 and the daily average firebox
temperature at or above 1200 oF shall be maintained
during periods of startup and shutdown
Continuous (at least once every 15 minutes) and hourly
O2 monitoring data shall be collected according to
§63.1572 and the O2 concentration at or above 2
volume percent (dry basis) shall be maintained during
periods of startup and shutdown
Performance testing on the sulfur recovery plants shall comply
with requirements specified in §63.1568(b)(5), S63.1571(b) and
§63.1572(a) of MACT UUU.
§63.1568(b)(5)
§63.1571(b)
§63.1572(a)(2)
Table 33, No. 1a, MACT UUU
Annual compliance testing shall be conducted on each sulfur
recovery system for SO2 emissions.
Rule 335-3-16-.05(c)(1)(ii)
Performance test or CEMS performance evaluations reports shall be
submitted to the Department within 60 days of the test date and
according to the requirements specified in §63.1575(k).
§63.1575(k)
A root cause analysis and a corrective action analysis shall meet the
following requirements for Tail Gas Incidents:
Rule 335-3-16-.05(c)(2)
The requirements shall apply to tail gas unit (TGU) shutdowns,
bypasses of a TGU, or other events which result in a Tail Gas
Incident, including scheduled and unscheduled shutdowns of
the Claus Sulfur Recovery Plant.
Shall be completed as soon as possible, but no later than forty-
five (45) days after a discharge.
Corrective actions identified in the corrective action analysis
shall be consistent with good engineering practice to minimize
the likelihood of a recurrent of the Root Cause and all significant
contributing causes of that Tail Gas Incident.
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (n) of this
section of this subpart shall be maintained and made available for
inspection.
§§63.1576(a),(b), (d),(g)-(I)
Rule 335-3-16-.05(c)(2)
§60.107
208
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
For the Assist gas, the Permittee must record:
Assist gas BTU content
[ Assist Gas (BTU/scf/)]
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Assist gas hydrogen sulfide content
[Assist Gas (H2S Mole %)]
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Provided the Assist Gas is the same as the fuel gas used
in the heaters and boilers, the Permittee may elect to
use those records to satisfy provisos 1(a)(1) and 1(a)(2).
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
The date, starting time, and duration of each deviation from the
requirements specified in this subpart along with the cause and
corrective actions taken.
§63.1570(f)
§63.1572(d)
For each Tail Gas Incident, the following record shall be
maintained onsite:
Rule 335-3-16-.05(a)
The date, time, and duration of each Tail Gas Incident,
along, if applicable, with the date, time, and duration of
each sub-Incident
An estimate of the quantity of the SO2 emissions
released for Tail Gas Incidents if the SO2 concentration
is greater than 250 ppmv
Steps taken to minimize emissions and/or the duration
of the event
A detailed analysis describing the Root Cause and any
contributing cause(s) to the Incident
A description of the plan(s) to minimize the recurrence
of the Incident, including possible operational changes,
cost effectiveness, and completion schedule.
A list of all corrective actions taken
A copy of the Preventative Maintenance and Operation [PMO]
Plan, along with any revisions.
Rule 335-3-16-.05(a)
The date, time, and results of each performance test along with
any other test conducted on the thermal oxidizer that provides
additional stack pollutant content data.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
§63.1576(a)(3)
209
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
The date and time of each shut down and startup of the gas
sweetening unit, the sulfur recovery unit, the tail gas unit, or the
thermal oxidizer.
§63.1576(a)(2)
Date and type of maintenance that affects air emissions Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Records of performance tests, performance evaluations, and
opacity and visible emissions observations as specified in
§63.10(b)(2)(viii) of Subpart A, where applicable
§63.1576(a)(3) & (c)
The hourly and twelve hour rolling average sulfur dioxide
concentration for both thermal oxidizers
§63.1568(c)(1)
The 365-day rolling average for Thermal Oxidizer No. M.1801 Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Rule 335-3-14-.04 [Anti-PSD
Limit]
For each CEMS, the records specified in §63.1576(b)(1)-(5) shall
be maintained for sulfur recovery systems.
§63.1576 (b) & (d)
Current copy of the operations, maintenance, and monitoring
plan maintained onsite and available for inspection.
§63.1576(e)
A copy of all notifications and reports submitted per MACT
UUU, including for start-ups, shutdowns, and malfunctions.
§63.1576(a)(1) & (a)(2)
Where applicable, exemption records demonstrating that the
fuel gas burned in the thermal oxidizer is inherently low in
sulfur.
§60.107(e)
Records shall be maintained as follows: §63.10(b)(1), §63.1576(g)-(i)
§64.9
In a form suitable and readily available for expeditious review
according to §63.10(b)(1) of Subpart A
Records must be kept for a period of 5 years following the date
of each occurrence, measurement, maintenance, corrective
action, report, or record.
Records must be maintained onsite for at least 2 years following
the date of each occurrence, measurement, maintenance,
corrective action, report, or record. Records may be maintained
offsite for the remaining 3 years.
210
Provisos for Sulfur Recovery Systems & Thermal Oxidizers
Federally Enforceable Provisos Regulations
The following reporting requirements shall be met:
An Excess Emissions report and/or summary shall be submitted
to the Department and shall contain the applicable information
specified in §60.105(e) and §60.107(d) and (g) of NSPS J.
§60.7(c)
§60.105(e)(3), (4)
§60.107(d) & (g)
A Compliance Report shall include any 12-hour rolling average
concentration of SO2 greater than the emission limit and the
information specified in §63.1575(c)-(f) of MACT UUU.
§63.1568(c)(1). §63.1570(f)
§63.1575(a), (c)(4)
Table 43, No. 1, MACT UUU
A Periodic Monitoring Report (PMR) shall identify each
incidence of deviation from a permit term or condition including
those that occur during startups and shutdowns which are not
covered under NSPS J or MACT UUU.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups, shutdowns, and malfunctions.
§63.1570(f)
§63.1575(c)(4) or (d)
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the
permit that can be used to determine or indicate
compliance, that identifies an affected source has failed
to meet an applicable emission limit or standard, or that
a work practice was not complied with or completed.
If there are no deviations events that occurred during
the reporting period, a statement that indicates there
were no deviations from the permit requirements shall
be included in the report.
Each report shall be submitted semi-annually on the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1 - December 31 February 28
Rule 335-3-16-.05(c)(2)
§60.7(c), (d), §60.19(d), (e)
§60.107(f)
§63.1575(b)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the general proviso subpart of
this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
211
Summary Page for NSPS Ja & MACT CC: Process Flares and Associated
Process Unit Vents
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD * REGULATIONS
FLARES WITH INTERCONNECTED FLARE GAS RECOVERY UNIT (FGRU)
BTZ-US-54C
D10.3301
M-2201
HYDROCRACKER AREA, STEAM ASSISTED
PROCESS FLARE
HYDROBON AREA, STEAM ASSISTED,
PROCESS FLARE
COKER AREA (WEST), STEAM ASSISTED,
PROCESS FLARE
H2S Burn Gas with 0.10 grains of H2S per
scf (gr/dscf)
<20 ppbv H2S offsite
Fuel gas <162 ppmv determined on
a 3-hour rolling average basis
Rule 335-3-5-.03(1)
Rule 335-3-5-.03(2)
§60.103a(h)
[NSPS Ja]
HAPs
Pilot flame present at all times
when regulated material routed to
the flare
§63.670 b)
[MACT CC]
Flare tip velocity must meet
allowable specified in §63.670(d)(1)
or (2)
§63.670(d)
[MACT CC]
NHVcz operated and maintained at
or above 270 Btu/scf based on a 15-
minute block period
§63.670 (e)
[MACT CC]
STF-2-24C CRUDE AREA (EAST), STEAM ASSISTED,
PROCESS FLARE W/FGRU
H2S Burn Gas with 0.10 grains of
H2S per scf (gr/dscf)
Rule 335-3-5-.03(1)
<20 ppbv H2S offsite Rule 335-3-5-.03(2)
Fuel gas <162 ppmv determined on
a 3-hour rolling average basis
§60.103a(h)
[NSPS Ja]
HAPs
Pilot flame present at all times
when regulated material routed to
the flare
§63.670(b)
[MACT CC]
Flare tip velocity must meet
allowable specified in §63.670(d)(1)
or (2)
§63.670 (d)
[MACT CC]
NHVcz operated and maintained at
or above 270 Btu/scf based on a 15-
minute block period
§63.670 (e)
[MACT CC]
EACH FLARE
Opacity Smokeless design capacity,
Except for five (5) minutes in a 2
consecutive hour period as allowed
§63.670 (c)
[MACT CC]
*Limits for each Flare
212
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
EACH ASSOCIATED MISCELLANEOUS PROCESS VENT
(INCLUDING MAINTENANCE VENTS) UNIT IN VOC AND/OR
HAPS SERVICE THAT VENTS TO FLARES OR FGRU
HAPS Route to FGRU, Closed Vent
System, & Flare OR to a Fuel
Gas System
§63.642(k), §63.643(a),
§63.643 (c)(1)(ii);
§63.660(i)(1), §63.670
[MACT CC]
DELAYED COKING UNITS
COKE DRUM A
COKE DRUM B
COKE DRUM C
COKE DRUM D
VOC Uncondensed vapors must be
recovered or vented to the
fuel gas system, a fuel gas
combustion device or flare
§60.103a(i)
[NSPS Ja]
PROCESS UNIT TURNAROUNDS VOC Depressure process unit or
vessel to a Vapor Recovery
System, Flare, or Firebox;
VOCs shall not be emitted
from a process unit or vessel
until its internal pressure is
19.6 psia [5 psig], or less
Rule 335-3-6-.08
213
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
Applicability
Each flare shall be subject to the requirements specified in ADEM
Admin. Code r. 335-3-16, “Major Source Operating Permits”, and the
requirements specified in this subpart of this permit.
Rule 335-3-16-.03
§60.1(c)
§63.642(a)
The refinery handles gas or refinery gas that contains hydrogen sulfide
(H2S) concentrations of 0.10 grains or more per standard cubic foot (scf);
therefore, it is subject to the requirements of ADEM Admin. Code r. 335-
3-5-.03, “Petroleum Production”, and the requirements specified in this
subpart of this permit.
Rule 335-3-5-.03(2)
The refinery is subject to the requirements of ADEM Admin. Code r. 335-
3-6-.08, “Petroleum Refinery Sources” for vacuum producing systems
and process unit turnarounds and the requirements specified in this
subpart of this permit.
Rule 335-3-6-.08
Each flare is subject to the applicable requirements of 40 CFR 60 Subpart
A, “General Provisions” as specified in the applicable subpart under 40
CFR Part 60, and the requirements specified in this subpart of this
permit.
§60.1
Each flare and each coke drum vent shall demonstrate compliance with
the requirements of 40 CFR Part 60, Subpart Ja ”Standards of
Performance for Petroleum Refineries” [NSPS Ja] and the requirements
specified in this subpart of this permit.
§60.100a(a), (b) and (c)(1)
Rule 335-3-16-.05(a)
Each flare used as a control device for an emission point subject to this
subpart shall be subject to the requirements specified in 40 CFR 63
Subpart, CC “National Emission Standards for Hazardous Air Pollutants
(HAPs) from Petroleum Refineries” [Refinery MACT 1/MACT CC] and the
requirements specified in this subpart of this permit.
§63.640 (a), (n)(8)(vii),
(n)(10)(viii), (o)(2)(i)(D),
(o)(2)(ii)(C), (s)
§64.2(b)(1)(i)
Per §64.2(b)(1)(i), the flares would be exempt from the
requirements of 40 CFR 64, “Compliance Assurance Monitoring”
[CAM}. Compliance with MACT CC shall meet the requirements
CAM.
§61.2(b)(1)(i)
Each flare is subject to the applicable requirements of 40 CFR
63 Subpart A, “General Provisions” as specified in the applicable
subpart under 40 CFR Part 63 and the requirements specified in
this subpart of this permit
§63.1, §63.642(c)
Table 6, 40 CFR 63 Subpart CC
214
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
Emission Standards
Each flare shall comply with the following requirements, except for
periods of start-up, shutdown, relief valve leakage, and/or process
malfunction when process gases or fuel gases are released to the flare:
All process gas streams containing more than 0.10 grain of H2S
per scf (~160 parts per million (ppmv)) shall be burned to the
extent that the ground level concentrations of H2S shall be less
than twenty (20) parts per billion (ppbv) beyond plant property
limits, averaged over a thirty (30) minute period.
Rule 335-3-5-.03(2)
Provided vessels or equipment are being de-pressured and/or
emptied and the reduced pressure will not allow flow of the
process gas stream to the combustion device, venting to
atmosphere of any gas stream shall be allowed, but the
duration of the venting shall not exceed 15 continuous minutes.
Rule 335-3-5-.03(2)
During a process unit turnaround, depressurization venting of the
process unit, or vessel shall occur to a vapor recovery system, flare, or
firebox, and VOCs shall not be emitted from a process unit or vessel until
its internal pressure is 19.6 psia [5 psig], or less.
Rule 335-3-6-.08(4)
The following requirements shall be met for flares to demonstrate
compliance with NSPS Ja:
§60.103a(f)
§60.103a(b)(1)
A written flare management plan (FMP) shall be developed and
implemented as specified in §60.103a(a) and §60.103a(b) of
NSPS Ja.
§60.103a(a)(1)-(7),(b)
Except for the combustion in the flare of process upset gases or
fuel gas that is released to the flare as a result of relief valve
leakage or other emergency malfunction, any fuel gas that
contains H2S in excess of 162 ppmv determined hourly on a 3-
hour rolling average basis shall not be burned in any flare.
§60.103a(h)
An alternative means of emission limitation may be requested
to comply with this subpart as specified in §60.103a(j).
§60.103a(j)
For sulfur monitoring, a root cause analysis (RCA) and a
corrective action analysis (CAA) shall be conducted on each
flare when one of the conditions below occurs. Special
circumstances affecting the number of RCA and/or CAA are
specified in §60.103a(d).
§60.103a(c)(1), §60.103a(d)
§60.103a(f), §60.107a(g)
Rule 335-3-16-.05(a)
215
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
Any time the sulfur dioxide (SO2) emissions exceeds 227
kilograms (kg) (500 Lb) in any 24-hour period
Any discharge to the flare in excess of 14,160 standard
cubic meters (m3) (500,000 standard cubic feet) above
the baseline flow in any 24-hour period determined as
specified in §60.103a(a)(4) (see FMP)
Any period when the flare gas line pressure exceeds the
water seal liquid depth (if the monitoring alternative
specified in §60.107a(g) is elected).
For delayed coking units to demonstrate compliance with NSPS Ja, until
the coke drum internal pressure reaches 5 pounds per square inch
gauge (psig), the coke drum steam exhaust must be managed in an
enclosed blowdown system and the uncondensed vapor must either be
recovered or vented to the fuel gas system, a fuel gas combustion
device, or a flare.
§60.103a(i)
The applicable requirements specified in §63.670 (a) through (q) of
MACT CC shall be met at all times except that an alternative means of
emission limitation (as specified in §63.670 (r)) may be requested to be
used in lieu of the requirements specified in §63.670 (d) through (f).
§63.642(b)
§63.670 (a) through (q)
§63.670 (r)
Regulated material means any stream associated with emission
sources listed in §63.640(c) required to meet control
requirements under this subpart as well as any stream for which
this subpart or a cross-referencing subpart specifies that the
requirements for flare control devices in §63.670 must be met.
§63.641
Each flare shall operate with a pilot flame present at all times
when regulated material can be routed to the flare.
§63.670(b)
The smokeless design capacity of each flare shall be specified
and each flare shall be operated with no visible emissions
except for periods not to exceed a total of five (5) minutes
during any 2 consecutive hours when regulated material is
routed to the flare and the flare vent gas flowrate is less than
the smokeless design capacity of the flare.
§63.670(c)
Provided the appropriate monitoring systems are in place
whenever regulated material is routed to the flare for at least
15-minutes and the flare vent gas flow rate is less than the
smokeless design capacity of the flare; one the following flare
tip velocity (Vtip) requirements shall be complied with.
§63.670(d)
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The actual flare Vtip must be less than 60 feet per
second.
§63.670(d)(1)
The Vtip must be less than 400 feet per second and also
less than the maximum allowed flare tip velocity (Vmax)
as determined in §63.670(d)(2).
§63.670(d)(2)
Each flare shall be operated to maintain the net heating value
of the flare combustion zone gas (NHVcz) at or above 270 British
thermal units per standard cubic feet (Btu/scf) determined on a
15-minute block period basis when regulated material is routed
to the flare for at least 15-minutes.
§63.670(e)
At all times any affected source, including associated air
pollution control equipment and monitoring equipment, must
be operated and maintained, in a manner consistent with safety
and good air pollution control practices for minimizing
emissions as specified in §63.642(n).
§63.642(n)
At all times and to the extent practicable, including during periods of
startup, shutdown, and/or malfunction (SSM), good air pollution control
practices for minimizing emissions consistent with 40 CFR §60.11(d) of
subpart A shall be implemented.
§60.11(d)
§60.103a(a)(5)
§63.642(g)
Each flare shall be equipped with a flare gas recovery system that meets
the following requirements:
Rule 335-3-16-.05(a)
Except during maintenance activities, the flare gas recovery
system shall be in operation at all times in which process gases
may be sent to the flare.
The gas streams captured by the flare gas recovery system shall
be routed to the fuel gas sweetening system.
Compliance and Performance Test Methods and Procedures
To determine compliance with the H2S concentration requirement in
§60.103a(h) the following requirements shall be met:
§60.104a(a)
Performance tests shall be completed utilizing one of the
following methods:
§60.104a(a), §60.104a(c)
§60.104a(j)(4), §60.107a(a)(2)
EPA Method 11 of appendix A-5 to part 60, and as
specified in §60.104a(j)(4)(i)
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EPA Method 15 of appendix A-5 to part 60, and as
specified in §60.104a(j)(4)(ii)
EPA Method 15A of appendix A-5 to part 60, and as
specified in §60.104a(j)(4)(iii). Method ANSI/ASME PTC
19.10-1981, “Flue and Exhaust Gas Analysis,”
(incorporated by reference-see §60.17) is an
acceptable alternative to EPA Method 15A of Appendix
A-5.
EPA Method 16 of appendix A-6 to part 60
An H2S monitoring system shall comply with the following
requirements:
§60.107a(a)(2)
Each H2S monitor shall be installed, operated, and
maintained according to Performance Specification 7 of
40 CFR 60 Appendix B.
§60.107a(a)(2)(i)
Performance Evaluations for each H2S monitor shall be
conducted according to the requirements of §60.13(c)
of subpart A and to performance specification 7 of 40
CFR 60 Appendix B
§60.107a(a)(2)(ii)
Relative Accuracy Evaluations shall be conducted using
Methods 11, 15, or 15A* of 40 CFR 60 Appendix A-5 OR
Method 16 of 40 CFR 60 Appendix A-6
§60.107a(a)(2)(ii)
*Method ANSI/ASME PTC 19.10-1981, “Flue and
Exhaust Gas Analysis,” (incorporated by reference-see
§60.17) is an acceptable alternative to EPA Method 15A
of Appendix A-5.
The quality assurance procedures specified in 40 CFR 60
Appendix F shall be complied with for each H2S monitor.
§60.107a(a)(2)(iii)
If the composition of an exempt fuel gas stream changes, the
procedures specified in §60.107a(b)(3) shall be met.
§60.107a(a)(4)
§60.107a(b)(3)
Sulfur monitoring for assessing root cause analysis thresholds shall be
met by equipping the flares with a total reduced sulfur (TRS) monitor
and complying with the following methods and procedures specified in
NSPS Ja:
§60.107a(e)
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Each monitor shall be installed, operated, and maintained
according to Performance Specification 5 of 40 CFR 60 Appendix
B.
§60.107a(e)(1)(i)
Performance Evaluations for each TRS monitor shall be
conducted according to the requirements of §60.13(c) of
subpart A and to Performance Specification 5 of 40 CFR 60
Appendix B.
§60.107a(e)(1)(ii)
Relative Accuracy Evaluations shall be conducted using one of
the following methods:
§60.107a(e)(1)(ii)
Methods 15A of 40 CFR 60 Appendix A-5 OR Method
ANSI/ASME PTC 19.10-1981, “Flue and Exhaust Gas
Analysis,” (incorporated by reference-see §60.17)
§60.107a(a)(1)(ii)
The alternative relative accuracy procedures specified
in section 16.0 of Performance Specification 2 of 40 CFR
60 Appendix B (cylinder gas audits) may be utilized
except that it is not necessary to include as much of the
sampling probe or sampling line as practical
§60.107a(a)(1)(ii)
The quality assurance procedures specified in 40 CFR 60
Appendix F shall be complied with for each TRS monitor.
§60.107a(e)(1)(iii)
Each flow monitor shall be installed, calibrated, operated, and
maintained according to manufacturer’s procedures and specifications.
§60.107a(f)(1)
When applicable, the following test methods and procedures shall be
used to demonstrate compliance with the requirements of MACT CC:
Visible emission observations shall be conducted in accordance
with Method 22 of 40 CFR part 60, appendix A-7.
§63.670(c), §63.670(h)
The procedures specified in §63.670(i) and (k) shall be used to
monitor the actual flare tip velocity (Vtip).
§63.670(d)(1)
63.670(i), (k)
The procedures specified §63.670(j) and (l) shall be used to
monitor the gas composition and determine the net heating
value of the vent gas (NHVvg), except that an alternative to 40
CFR 60 Appendix B, PS 9 may be approved by EPA to determine
the net heating value.
§63.670(d)(2)
63.670(j), (l)
§63.7(f)
The procedures specified in §63.670(m) shall be used to
calculate the combustion zone net heating value (NHVcz).
§63.670(e), §63.670(m)
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Emission Monitoring
Periodic Monitoring meeting the requirements specified in Appendix D:
Facility Flares Monitoring of this permit shall be met to demonstrate
that the H2S offsite concentration requirement is being met.
Rule 335-3-5-.03(2)
Rule 335-3-16-.05(c)1(ii)
When performance testing is required under NSPS Ja to determine the
H2S concentration of the fuel gas for the flares, the following
requirements shall be met in accordance with the requirements of
§60.8:
§60.8
§60.104a(a)
§60.104a (j)(4)
§60.104a (j)(4)(iv)
If monitoring is conducted at a single point in a common source
of fuel gas as allowed under §60.107a(a)(2)(iv), only one
performance test is required.
Performance tests are not required when a new affected flare
is added to a common source of fuel gas that has previously
demonstrated compliance.
Compliance may be based on the mixture used in the flare or
for each individual fuel gas stream used in the flare.
Except when the exemptions found in §60.107a(b) for low-sulfur fuel
gas streams apply, an instrument for continuously monitoring and
recording the concentration by volume (dry basis) of H2S in the fuel
gases before being burned in any flare shall be installed, operated,
calibrated, and maintained to demonstrate compliance with the H2S
concentration requirement in §60.103a(h) of NSPS Ja.
§60.107a(a)(2)
§60.107a(a)(3)
§60.107a(b)
The span value for the instrument is 300 ppmv H2S.
Flares having a common source of fuel gas may be monitored
at only one location if monitoring at this location accurately
represents the concentration of H2S in the fuel gas being
burned in the respective flares.
Except for flares exempt from monitoring as specified §60.107a(e)(4),
an instrument for continuously monitoring and recording the
concentration of TRS in gas discharged to the flare shall be installed,
operated, calibrated, and maintained to demonstrate compliance with
the root cause analysis (RCA) threshold under NSPS Ja.
§60.107a(e)
§60.107a(e)(1)
§60.107a(e)(4)
The span value for the instrument shall be determined based on
the maximum sulfur content of gas that can be discharged to
flare but no less than 5,000 ppmv.
§60.107a(e)(1)(i)
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A dual range monitor may be used to comply with the
requirement provided that the applicable span specifications
are met.
§60.107a(e)(1)(i)
Each RCA and CAA shall be completed as soon as possible, but
no later than 45 days after a discharge.
§60.103a(b)(1), §60.103a(d)
§60.108a(c)(6)
Corrective action(s) as specified in §60.103a(e) shall be
implemented as identified in the CAA.
§60.103a(e)
Except as specified in §60.107a(f)(2), a continuous parameter
monitoring system (CPMS) shall be installed, operated, calibrated, and
maintained to measure and record the flow rate of gas discharged to
the flares.
§60.107a(f)
§60.107a(f)(2)
The following monitoring requirements shall be met to demonstrate
compliance with MACT CC:
For pilot flame monitoring, the presence of the pilot flame(s)
must be continuously monitored using the continuous
parameter monitoring system (CPMS) installed to detect the
presence of a pilot flame
§63.670(b)
§63.670(g)
For visible emission monitoring §63.670(c), §63.670(h)
The first-time regulated materials are routed to the
flare, an initial visible emissions demonstration shall be
conducted for an observation period of 2 hours.
§63.642(d)
§63.670(h)
Subsequent visible emission observations may be
conducted at least once per day, using an observation
period of five (5) minutes, for each day regulated
material is routed to the flare
§63.670(h)(1)
(i) If at any time the owner or operator sees visible
emissions while regulated material is routed to
the flare, even if the minimum required daily
visible emission monitoring has already been
performed, the owner or operator shall
immediately begin an observation period of 5
minutes
221
Provisos for Process Flares and Associated Process Unit Vents
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(ii) If visible emissions are observed for more than
one continuous minute during any 5-minute
observation period, the observation period
must be extended to 2 hours or until 5-minutes
of visible emissions are observed.
(iii) Daily 5-minute observations are not required to
be conducted for days the flare does not
receive any regulated material.
For flare vent gas, steam assist, and air assist flow rate
monitoring:
§63.670(d)(1) and (2)
§63.670(i)
A monitoring system capable of continuously
measuring, calculating, and recording the volumetric
flow rate in the flare header or headers that feed the
flare as well as any flare supplemental gas used shall be
installed, operated, calibrated, and maintained.
Different flow monitoring methods may be used to
measure different gaseous streams that make up the
flare vent gas provided that the flow rates of all gas
streams that contribute to the flare vent gas are
determined
If assist air or assist steam is used, a monitoring system
capable of continuously measuring, calculating, and
recording the volumetric flow rate of assist air and/or
assist steam used with the flare shall be installed,
operated, calibrated, and maintained.
If pre-mix assist air and perimeter assist are both used,
a monitoring system capable of separately measuring,
calculating, and recording the volumetric flow rate of
premix assist air and perimeter assist air used with the
flare shall be installed, operated, calibrated, and
maintained.
Flow monitoring system requirements and acceptable
alternatives are specified in §63.670(i)(1) through (6).
For flare vent gas composition monitoring, the requirements
specified in §63.670(j) shall be met, except that a process mass
spectrometer analyzer may be used as an alternative to
measure the NHVvg as approved by EPA.
§63.670(d)(2)
§63.670(j)
§63.7(f)
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Provisos for Process Flares and Associated Process Unit Vents
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Cumulative flow rates and compliance with Vtip operating limits
shall be determined on a 15-minute block average
basis according to the requirements specified in §63.670(k).
§63.670(d)(1) and (2)
§63.670(k)
The net heating value of the flare vent gas (NHVvg) shall be
determined based on the composition monitoring data on a 15-
minute block average basis according to the requirements
specified in §63.670(l).
§63.670(d)(2)
§63.670(l)
Except as specified in §63.670(m)(2), the net heating value of
the combustion zone gas (NHVcz) shall be determined in 15-
minute block average NHVcz based on the 15-minute block
average vent gas and assist gas flow rate.
§63.670(e)
§63.670(m)
A flare that has the potential to operate above its smokeless
capacity under any circumstances shall comply with
the Emergency Flaring provisions specified in §63.670(o).
§63.670(o)
The flare monitoring system installed on each flare to comply with
MACT CC shall meet the following requirements:
§63.671
Each continuous parameter monitoring system (CPMS) installed
to comply with applicable provisions in §63.670 shall be
installed, operated, calibrated, and maintained as specified in
§63.671(a).
§63.671(a)
A CPMS quality control program documented in a CPMS
monitoring plan that covers each flare subject to the provisions
in §63.670 and each CPMS installed to comply with applicable
provisions in §63.670 shall be developed and implemented.
§63.671(b)
The CPMS monitoring plan must be readily available on-
site at all times and a copy of the CPMS monitoring plan
shall be submitted to the Department upon its request.
The CPMS monitoring plan must contain the
information listed in paragraphs §63.671 (b)(1) through
(5) of this section.
Except for CPMS installed for pilot flame monitoring, each
CPMS installed to comply with applicable provisions in §63.670
shall comply with the out-of-control procedures described in
paragraphs §63.671 (c)(1) and (2).
§63.671 (c)
223
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
Data from the CPMS installed to comply with applicable
provisions in §63.670 shall be reduced as specified in
§63.671 (d)(1) through (3).
§63.671 (d)
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (d) of this
section of this subpart shall be maintained and made available for
inspection.
The date, starting time, and duration of each deviation from the
requirements specified in this subpart along with the cause and
corrective actions taken.
Rule 335-3-16-.05(c)(2)
Results of each visual emission observation Rule 335-3-16-.05(c)(2)
Monitoring reports meeting the requirements specified in proviso 2(a)
through (d) of this section of this subpart shall be submitted to the
Department.
Rule 335-3-16-.05(c)(3)(i)
§60.7(c),§60.10, §60.107a(f),
§60.108a(d), §60.107a(i)(2)(i)-
(ii), §60.107a(i)(2)(i)
(a) Each report shall identify each incidence of deviation from a
permit term or condition including those that occur during
startups, shutdowns, and malfunctions
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping protocol which is required by
the permit that can be used to determine or indicate
compliance, that identifies an affected source has failed
to meet an applicable emission limit or standard, or
that a work practice was not complied with or
completed
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
Each Excess Emissions Report shall meet the requirements
specified in §60.7(c) of 40 CFR Part 60, Subpart A.
Except as provided for in proviso 2(e) of this section, the report
shall include the following information for each deviation event:
Emission source description
224
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
Permit requirement
Date
Starting time
Duration
Actual quantity of pollutant or parameter
Cause
Actions taken to return to normal operating conditions
Total operating hours of the affected source during the
reporting period
Total hours of deviation events during the reporting
period
Total hours of deviation events that occurred during
startups, shutdowns, and malfunctions during the
reporting period
Each report shall cover a semi-annual reporting period and shall
be submitted according to the following reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
The report content specified in provisos 2(c) of this section may
be modified upon receipt of Departmental approval.
To demonstrate compliance with NSPS Ja, the following requirements
shall be met:
The notification, recordkeeping, and reporting requirements
specified in §60.7 of subpart A shall be maintained.
§60.108a(a)
The following records shall be maintained for the flares: §60.108a(c)
Copy of the flare management plan (FMP) §60.108a(c)(1)
225
Provisos for Process Flares and Associated Process Unit Vents
Federally Enforceable Provisos Regulations
For each fuel gas stream meeting the exemptions found
under §60.107a(a)(3), a record of the specific
exemption determined to apply for each fuel stream
shall be maintained.
§60.108a(c)(5)
Records of discharges greater than 500 Lbs of SO2 in any
24-hour period from each flare.
§60.108a(c)(6)
Records of discharges to each flare in excess of 500,000
scf above baseline in any 24-hr period as required by
§60.103a(c).
§60.108a(c)(6)
The applicable information specified in
§60.108a(c)(6)(i) through (xi) shall be recorded no later
than 45 days following the end of a discharge exceeding
the thresholds specified in provisos 3(c)(3) and (4) of
this section.
§60.108a(c)(6)(i)-(xi)
An Excess Emission Report shall be submitted for all periods of
excess emissions for which a continuous monitoring device is
installed.
§60.108a(d)
§60.7(c)
The report shall be submitted according to the
requirements of §60.7(c) except that the information
specified in §60.108a(d)(1) through (7) shall be included
in the report.
Each report shall cover a semi-annual reporting period
and shall be submitted according to the following
reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
The following requirements shall be met to demonstrate compliance
with the recordkeeping and reporting requirements under MACT CC:
The recordkeeping requirements shall be met for the flares as
follows:
§63.642(e), §63.655(i)
§63.655(i)(9), §63.670(p)
Records specified in §63.655(i)(9)(i) through (xii) shall
be up-to-date and maintained.
226
Provisos for Process Flares and Associated Process Unit Vents
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Copies of all applicable reports and records shall be
kept for at least 5 years except as otherwise specified
in §63.655(i).
All applicable records shall be maintained in such a
manner that they can be readily accessed within 24
hours.
Records may be maintained in hard copy or computer-
readable form including, but not limited to, on paper,
microfilm, computer, flash drive, floppy disk, magnetic
tape, or microfiche.
A Notification of Compliance Status (NOCS) Report shall be
submitted as specified in §63.655(f).
§63.655(e)(1)
§63.655(f)
§63.655(g)(14)
A Periodic Report meeting the following requirements shall be
met for the flares:
§63.642(f)
§63.655 (e)(2) and (g)
§63.670(q)
The requirements specified in §63.655(g)(11)(i) through
(iv) shall be included in the report.
§63.655(g)(11)
Reports shall be submitted to the Department on a
semi-annual calendar basis according to the following
reporting schedule:
Reporting Period Submittal Date
January 1-June 30 August 28
July 1- December 31 February 28
§63.642(f)
§63.655(g)
A Periodic Report is not required if no events specified
in §63.655(g)(11) occurred during the reporting period.
§63.655(g)
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the General Provisos subpart
of this permit.
Rule 335-3-16-.05(c)3(ii)
227
Summary Page for MACT LLLLL: Asphalt Processing Facility & Thermal Oxidizer
Permitted Operating Schedule†: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year
Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission Limitations:
EMISSION
POINT DESCRIPTION POLLUTANT
EMISSION
LIMIT/STANDARD REGULATIONS
ALL SOURCES
For charge rate [P] < 30 Ton/hr Particulate [3.59] X [P]^ 0.62 Rule 335-3-4-.04(1)
For charge rate [P] ≥ 30 Ton/hr Particulate [17.31] X [P]^ 0.16 Rule 335-3-4-.04(1)
INDIVIDUAL SOURCES
Cyclone, Knockout Drum & Thermal Oxidizer
THOX 25.6 MMBTU/Hr Thermal Oxidizer NOX ≤ 8.00 Lbs/Hr Rule 335-3-14-.04
[Anti-PSD Limit]
OHAP Capture and route vapors from
each blowing still to the Thermal
Oxidizer to achieve a combustion
efficiency of 99.5 %
§63.8684(a)
[Asphalt MACT]
SO2 Burn assist gas that contains
H2S <162 ppmv
§60.104(a)(1)
[NSPS J]
Opacity No more than one 6 min avg. >
20%
Rule 335-3-4-.01(1)(a)
OR
No 6 min avg. > 40% in any sixty
(60) minute period Rule 335-3-4-.01(1)(b)
Blowing Stills (Controlled by the THOX) and Loading Spouts
T-14 800 Barrels per day (Bbls/Day) Blowing Still & Loading Spout
T-30X 1100 Bbls/Day, Blowing Still & Loading Spout
T-33 1100 Bbls/Day Blowing Still
T-50 800 Bbls/Day Blowing Still & Loading Spout
T-75 1100 Bbls/Day Blowing Still
GROUP 2 STORAGE VESSELS
Closed Vent System No. 1
T-006 1,850,453 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
Closed Vent System No. 2
T-041 187,144 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
T-043 187,144 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
T-045 187,144 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
T-047 187,144 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
Closed Vent System No. 3
T-099 1,729,835 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
Closed Vent System No. 4
T-077 3,383,898 gallon asphalt storage vessel Opacity 0% opacity §63.8684(a)
Closed Vent System No. 5
T-16 4,200,000 gallon storage vessel Opacity 0% opacity §63.8684(a)
228
Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
Applicability
The Asphalt Processing Facility and Thermal Oxidizer shall comply
with the requirements specified in ADEM Admin. Code r. 335-3-4-
.01(1)(a) and (b), “Visible Emissions”, and specified in ADEM Admin.
Code r. 335-3-4-.04(1), “Process Industries-General” for Control of
Particulate Emissions and the requirements specified in this subpart
of this permit. Provided that the requirements in ADEM Admin.
Code r. 335-3-4 are less stringent than the requirements specified
in ADEM Admin. Code r. 335-3-11, compliance shall be met by
complying with the more stringent regulation found in Chapter 335-
3-11.
Rule 335-3-4-.01(1)(a) and (b)
Rule 335-3-4-.04(1)
Rule 335-3-11-.01(2)
The Asphalt Processing Facility and thermal oxidizer (THOX) have
enforceable limits in place in order to avoid a review under ADEM
Admin. Code r. 335-3-14-.04, “Air Permits Authorizing Construction
in Clean Air Areas [Prevention of Significant Deterioration (PSD)],
and the requirements specified in this subpart of this permit.
Rule 335-3-14-.04
[Anti-PSD Limit]
The Asphalt Processing Facility and Thermal Oxidizer shall be subject
to the requirements specified in ADEM Admin. Code r. 335-3-16,
“Major Source Operating Permits”, and the requirements specified
in this subpart of this permit.
Rule 335-3-16-.03
The assist gas to the THOX shall be subject to the requirements
specified in 40 CFR 60 Subpart J, “Standards of Performance for
Petroleum Refineries” [NSPS J], the applicable requirements of 40
CFR 63 Subpart A, “General Provisions”, and the requirements
specified in this subpart of this permit.
§60.100(a)
40 CFR 30, Subpart A
Except as specified in §63.8681(b) through (e), blowing stills, Group
2 asphalt storage tanks, and a thermal oxidizer located at an asphalt
processing facility shall be subject to the requirements of 40 CFR 63
LLLLL, “National Emission Standards for Hazardous Air Pollutants:
Asphalt Processing and Asphalt Roofing Manufacturing” [Asphalt
MACT], and the requirements specified in this subpart of this
permit.
§63.8680, §63.8681
§63.8682(a), (b)(1), (c)
§63.8698
§64.2(b)(1)(i)
Blowing stills and asphalt storage tanks subject to the
requirements of 40 CFR 60 UU, “Standards of Performance
for Asphalt Processing and Asphalt Roofing Manufacture”
[NSPS UU] are only required to comply with the Asphalt
MACT.
§63.8681(b)
229
Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
Compliance with the applicable requirements of 40 CFR 63
Subpart A, “General Provisions” shall be met as specified in
Table 7 of the Asphalt MACT.
§63.8689
The Asphalt MACT does not apply to equipment subject to
40 CFR 63 Subpart CC or 40 CFR 60 Subpart K, Ka, or Kb.
§63.8681(c)
40 CFR 60 Subpart J, “Standards of Performance for
Petroleum Refineries” [NSPS J] does not apply to emissions
from asphalt processing facilities (including petroleum
refineries) subject to the Asphalt MACT, with the exception
of the exception of the assist gas for the asphalt THOX.
§63.8681(e)
Per §64.2(b)(1)(i), the thermal oxidizer would be exempt
from the requirements of 40 CFR 64, “Compliance
Assurance Monitoring” [CAM]. Compliance with MACT
LLLLL shall meet the requirements CAM.
§64.2(b)(1)(i)
Emission Standards
Visible emissions from the thermal oxidizer (THOX) shall meet the
opacity standards specified in proviso 1(a) and (b) of this section of
this subpart.
Rule 335-3-4-.01(a), (b)
The unit shall not discharge into the atmosphere particulate
that results in an opacity greater than 20%, as determined
by a 6-minute average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-minute
period, the unit shall not discharge into the atmosphere
particulate that results in an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
Particulate matter (PM10) from each asphalt blowing still and/or the
asphalt thermal oxidizer shall not exceed the allowable specified in
either proviso 2(a) or (b) of this section of this subpart.
Rule 335-3-16-.05(a)
Rule 335-3-4-.04(1)
Provided the charge rate is less than 30 Tons/Hour, the
allowed emissions shall be calculated as follows:
PM10 <= [3.59] X [Charge Rate (Tons/Hour)]0.62
Provide the charge rate is equal to or greater than 30
Tons/Hour, the allowed emissions shall be calculated as
follows:
PM10 <= [17.31] X [Charge Rate (Tons/Hour)]0.16
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The thermal oxidizer (THOX) shall comply with the following
requirements:
Nitrogen oxide (NOX) emissions shall not exceed 8.0 pounds
per hour (Lb/hr).
Rule 335-3-14-.04
[Anti-PSD Limit]
Only assist gas with a H2S content of less than or equal to
0.10 grains per dry standard cubic feet (gr/dScf) (162 ppmv)
over a 3-hour averaging period shall be burned.
§60.104(a)(1)
Vapors from each blowing still shall be captured and routed
to the thermal oxidizer and burned, such that the thermal
oxidizer maintains a 99.5% combustion efficiency.
§63.8684(a)
Table 1 No. 1(b), Asphalt MACT
Operational limits for the blowing stills shall be met by
maintaining the thermal oxidizer’s 3-hour average
combustion zone temperature at or above the operating
limit established during the most recent performance test.
A 15-minute averaging period can be used as an alternative
to the 3-hour averaging period for this parameter.
§63.8684(b)
Table 2, No. 1, subscript b
The operating limits are applicable if you are
monitoring control device operating parameters to
demonstrate continuous compliance.
Table 2, No. 1, subscript a, Asphalt
MACT
If you are using a continuous emission monitoring
system (CEMS) or continuous opacity monitoring
system (COMS), you must maintain emissions
below the value established during the initial
performance test.
Table 2, No. 1, subscript a, Asphalt
MACT
Each asphalt storage vessel at an asphalt processing facility shall
comply with the emission limitations found in Table 1 of the Asphalt
MACT and as specified in this section of this subpart:
§63.8684(a), Table 1, Asphalt
MACT
(a) Exhaust gases from each Group 2 asphalt storage tanks’
closed vent system and vent filter system shall be limited to
zero percent (0%) opacity.
§63.8684(a), Table 1, No. 4,
Asphalt MACT
The opacity limit can be exceeded for one
consecutive 15-minute period in any 24-hour
period when the storage tank transfer lines are
being cleared.
Table 1 subscript b, Asphalt MACT
During this 15-minute period, the control device
must not be bypassed.
Table 1 subscript b, Asphalt MACT
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As an alternative to meeting the opacity standards in
proviso 4(a) of this section of this permit, asphalt storage
tanks may comply with the total hydrocarbon (THC) percent
reduction as specified in Table 1, No. 1 or the combustion
efficiency standards specified in Table 1, No. 1(b) of the
Asphalt MACT.
Table 1, subscript a,
Asphalt MACT
The asphalt processing facility shall comply with the following
general standards specified in §63.8685 of the Asphalt MACT:
§63.8685
(a) Before September 9, 2020,
The emission limits and operational limits must be
met at all times, except during periods of startup,
shutdown, and malfunction.
§63.8685(a)
(The blowing still must be operated and
maintained, including the thermal oxidizer and
monitoring equipment, according to the provisions
in §63.6(e)(1)(i) of Subpart A.
§63.8685(b)
§63.6(e)(1)(i)
A written startup, shutdown, and malfunction plan
(SSMP) must be developed and implemented in
accordance with the provision in §63.6(e)(3) of
Subpart A.
§63.8685(c)
§63.6(e)(3)
On or after September 9, 2020,
The emission limits and operational limits must be
met at all times, except during nonoperation of the
affected source (or specific portion thereof)
resulting in cessation of the emissions.
§63.8685(a)
The blowing still must be operated and maintained,
including the thermal oxidizer and monitoring
equipment, in a manner consistent with safety and
good air pollution control practices for minimizing
emissions.
§63.8685(b)
A written site-specific monitoring plan shall be developed
and implemented in accordance with §63.8688(g) and (h) of
the Asphalt MACT.
§63.8685(d)
§63.8688(g), (h)
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Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards for the thermal oxidizer shall
be determined using Method 9 or Method 22 of 40 CFR Part 60,
Appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
Provided that testing is required to determine particulate matter
emissions, Method 5A of 40 CFR Part 60, Appendix A shall be used.
Rule 335-3-16-.05(c)(1)(i)
Provided that the assist gas combusted in the THOX is the same as
the fuel gas used in the heaters and boilers, the Permittee may elect
to use heater and boiler records to satisfy the test requirements for
the assist gas. Otherwise, performance evaluations of the H2S
monitor shall follow the procedures specified under §60.106(e)(1).
Rule 335-3-16-.05(c)(1)(i)
§60.105(a)(4)(ii)
§60.106(e)(1)
Performance testing shall be conducted in accordance with the
requirements specified in proviso 4(a) through (f) of this section of
this subpart.
NOX emissions shall be measured using Method 7E of 40 CFR
60 Appendix A.
Rule 335-3-16-.05(c)(1)(i)
The carbon monoxide (CO) concentration at the thermal
oxidizer outlet shall be measured using Method 10 of 40
CFR 60 Appendix A.
§63.8687(a), (b), (e)(3)
Table No. 3, No. 9(b)
The carbon dioxide (CO2) concentration at the thermal
oxidizer outlet shall be measured using Method 3A of 40
CFR 60 Appendix A.
§63.8687(a), (b), (e)(3)
Table No. 3, No. 9(a)
The total hydrocarbon concentration (THC) at the thermal
oxidizer outlet shall be measured using Method 25A of 40
CFR 60 Appendix A.
§63.8687(a), (b), (e)(3)
Table No. 3, No. 9(c)
The applicable methods specified Table 3, No. 1 through 4
of the Asphalt MACT shall be used as needed.
§63.8687(a), (b), (e)(3)
Table No. 3, Item Nos.1- 4
The methods and procedures may be modified upon
receiving Departmental approval.
Rule 335-3-16-.05(c)(1)(i)
For asphalt storage tanks’ vent filter systems, opacity observations,
shall be conducted utilizing Method 9 of 40 CFR part 60, Appendix
A.
Table No. 3, No. 7
Table No. 4, No. 5
The site-specific monitoring plan shall address the procedures
specified in §63.8688(h) of the Asphalt MACT.
§63.8688(h)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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A CPMS, CEMS, or COMS must be operated and maintained in
continuous operation according to the site-specific monitoring plan.
§63.8688(f), (j)
Determination of whether a source is operating in compliance with
operation and maintenance requirements will be based on, but is
not limited to, monitoring results, review of operation and
maintenance procedures, review of operation and maintenance
records, and inspections of affected sources.
§63.8685(b)
Emission Monitoring
A monitoring system that meets the requirements specified in the
§60.105(a)(4) of NSPS J and §60.13 of Subpart A shall be installed,
calibrated, maintained, and operated.
Rule 335-3-16-.05(c)(1)(ii)
§60.13
§60.105(a)(4)
§60.105(a)(4)(ii)
Periodic monitoring shall be conducted on the thermal oxidizer as
specified in Appendix E: Asphalt Processing System & Thermal
Oxidizer of this permit.
Rule 335-3-16-.05(c)(1)(ii)
§63.8688(a), (b), (f)
§63.8690, §63.8691(a)
Table No. 5, No. 1
Before September 9, 2020,
Except for monitor malfunctions, associated
repairs, and required quality assurance or control
activities (including as applicable calibration checks
and required zero and span adjustments), each
source must be monitored continuously (or collect
data at all required intervals) at all times including
startup, shutdown, and malfunction (SSM) when
the affected source is operating.
§63.8690(b), (c)
Each instance (including SSM), in which a source did
not meet each applicable operating limit in Table 5,
must be reported as a deviation according to
§63.8693.
§63.8691(b)
§63.8693
Consistent with §§63.6(e) and 63.7(e)(1),
deviations that occur during periods of SSM are not
violations if it is determined, by the Department,
that the unit was operating in accordance with
§63.6(e)(1). On or after September 9, 2020, this
requirement no longer applies.
§63.8691(d)
§63.6(e)
On and after September 9, 2020 and except during periods
of nonoperation of the affected source (or specific portion
thereof) resulting in cessation of the emissions to which this
subpart applies, the following requirements must be met:
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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Data must be monitored and collected at all times
in accordance with §63.8685(b).
§63.8685(b)
§63.8690(b), (c)
Each instance in which a source did not meet its
applicable operating limit in Table 5 must be
reported.
§63.8691(b)
Performance testing shall be conducted on the thermal oxidizer as
follows:
The requirements of §63.8687(a) and (b) of the Asphalt
MACT shall be met.
§63.8687(a), (b)
Each test shall consist of three runs of at least 1 hour in
duration each.
Rule 335-3-16-.05(c)(1)(i)
§63.7(e)(3)
§63.8687(d)
The following equation shall be used to indicate compliance
with the combustion efficiency standard for the thermal
oxidizer:
§63.8687(e)(3), (Eq. 5)
Combustion Efficiency [CE] =
[1 – (CO/CO2) – (THC/CO2)]
where,
CO = the CO concentration at the thermal oxidizer outlet
CO2 = the CO2 concentration at the thermal oxidizer outlet
THC = the Total Hydrocarbon concentration at the thermal
oxidizer outlet
During performance testing, the thermal oxidizer
combustion zone temperature shall be recorded every 15-
minutes and then averaged to yield the minimum operating
combustion zone temperature.
§63.8689(b)
§63.8691(a)
Table No. 3, No. 11
During the performance testing, the NOX emission factor
shall be determined in Lbs/MMBTU.
Rule 335-3-16-.05(c)(1)(i)
Except as specified in §63.8691(e)(3), subsequent
performance testing shall be conducted no later than 60
months following the previous performance test.
Rule 335-3-16-.05(c)(1)(ii)
§63.8687(a) and (b)
§63.8691(a)
§63.8691(e)(1), (3)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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The results of all emissions tests shall be submitted sixty
(60) days after the completion of the test.
Rule 335-3-16-.05(c)(1)(i)
An opacity test of each Group 2 asphalt storage tanks’ vent filter
systems shall be conducted as follows:
Table No. 3, No. 7
The requirements of §63.8687(a) and (b) of the Asphalt
MACT shall be met.
§63.8687(a) and (b)
Opacity observations shall be conducted for at least three
hours in order to obtain thirty (30) six-minute averages.
Table No. 4, No. 5
Except as specified in §63.8691(e)(3), subsequent periodic
testing shall be conducted no later than 60 months
following the previous performance test.
§63.8691(e)(1),(3)
The results of all emissions tests shall be submitted sixty
(60) days after the completion of the test.
§63.8692(e)
4. A performance evaluation must be conducted on each CPMS, CEMS,
or COMS in accordance to the site-specific monitoring plan.
§63.8688(i)
Recordkeeping and Reporting Requirements
Monthly records of the following data shall be maintained in a form
suitable for inspection for a period of five years. Only the last two
years are required to be kept onsite.
For the Assist gas, the Permittee must record: Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Assist gas heat content
[ Assist Gas Heat Content (BTU/scf) ]
Assist gas hydrogen sulfide (H2S) content §60.105(a)(4)
[ Assist Gas (H2S Mole %)]
Provided that the assist gas is the same as the fuel
gas used in the heaters and boilers, the Permittee
may elect to use those records to satisfy provisos
1(a)(1) and 1(a)(2) of this section of this permit.
§60.105(a)(4)(ii)
Assist gas volume to the Thermal Oxidizer
[ Assist Gas (Mscf/Month)]
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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Operating hours of the Thermal Oxidizer Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
[ THOX Hours/Month]
MMBTU of fuel gas consumption of the Thermal Oxidizer Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Assist Gas (MMBTU/Month) =
[ Assist Gas (Mscf/Month)] X [ Assist Gas (BTU/scf) ]
[1,000]
NOX emissions shall be determined for the Thermal Oxidizer
as follows:
THOX Emissions (Lbs/Month) =
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)
Rule 335-3-14-.04 [Anti-PSD]
[Assist Gas (MMBTU/Month)] X [Test (Lbs/MMBTU)]
where,
the Test (Lbs/MMBTU) shall be taken from the most recent
performance test
THOX Emissions (Lbs/Hour) =
[ THOX Emissions (Lbs/Month) ]
[ THOX Emissions (Hours/Month) ]
A Periodic Monitoring Report and/or Excess Emissions Report shall
be submitted to the Department for each permit requirement not
covered under the Asphalt MACT:
Rule 335-3-16-.05(c)(2), (c)(3)(i)
§60.7(c)
§60.105(e)(3)(ii)
Each report shall identify each incidence of deviation from
a permit term or condition including those that occur during
startups, shutdowns, and malfunctions
A deviation shall mean any condition determined
by observation, by data derived from any
monitoring or testing or recordkeeping protocol
which is required by the permit that can be used to
determine or indicate compliance, that identifies an
affected source has failed to meet an applicable
emission limit or standard, or that a work practice
was not complied with or completed
If no deviation event occurred during the reporting
period, a statement that indicates there were no
deviations from the permit requirements shall be
included in the report.
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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Except as provided for in proviso 2(d) of this section, the
report shall include the following information for each
deviation event:
Emission source description
Permit requirement
Date
Starting time
Duration
Actual quantity of pollutant or parameter
Cause
Actions taken to return to normal operating
conditions
Total operating hours of the affected source during
the reporting period
Total hours of deviation events during the reporting
period
Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a semi-annual reporting period and
shall be submitted to the Department according to the
following reporting schedule:
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
The report content specified in provisos 2(b) of this section
may be modified upon receipt of Departmental approval.
The following recordkeeping and reporting requirements shall be
met to demonstrate compliance with the Asphalt MACT:
The following records shall be maintained: §63.8694, §63.8695
238
Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
A copy of all notifications submitted to the
Department and EPA, as specified in
§63.10(b)(2)(xiv) of Subpart A.
§63.8694(a)(1)
Before September 9, 2020, all records related to
start-ups, shutdowns, and malfunctions, as
described in §63.6(e)(3)(iii) through (v) of Subpart A
shall be maintained. On or after this date, this
requirement is no longer required.
§63.8694(a)(2)
A copy of all performance tests, performance
evaluations, and visible emissions observations, as
described in §63.10(b)(2)(viii) of Subpart A shall be
maintained as follows:
§63.8694(a)(3)
(i) A notification of intent to conduct
performance tests shall be submitted to
the Department at least sixty (60) calendar
days prior to the test as required by
§63.7(b)(1) of Subpart A.
§63.7(b)(1)
§63.8692(d)
(ii) A Notification of Compliance Status (NOCS)
shall be submitted before close of business
the 60th calendar day following completion
of a performance test, design evaluation,
opacity observation, visible emission
observation, or other compliance
demonstration as follows:
§63.8692(e)
(A) Prior to September 9, 2020, the
NOCS shall be submitted according
to §63.9(h)(2)(ii).
(B) On or after September 9, 2020, the
NOCS must be submitted to EPA via
the Compliance and Emissions Data
Reporting Interface (CEDRI) which
can be accessed through EPA’s
Central Data Exchange (CDX)
(https://cdx.epa.gov/)
239
Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
(iii) If data from a previously-conducted
emission test is used to serve as
documentation of conformance with the
emission standards and operating limits,
test data must be submitted with the NOCS
in lieu of the initial performance test
results.
§63.8692(f)
(iv) A notification of the intent to conduct
opacity and visible emission observations
shall be submitted according to §63.9(f) of
subpart A
§63.9(f)
§63.8693(a)
Table 6, No. 3
(v) The results of all emissions tests shall be
submitted sixty (60) days after the
completion of the test
§63.8692(e)
Records specified in §63.6(h)(6) shall be maintained
for visible emission observations.
§63.8694(b)
Per No. 1 of Table No. 5 of the Asphalt MACT,
maintain a copy of the following records:
§63.8694(c)
Table 5, No. 1
(i) The hourly Thermal Oxidizer combustion
zone temperature
(ii) The hourly Thermal Oxidizer combustion
zone temperature reduced to 3-hour rolling
averages
Records of any shared equipment determinations
as specified in §63.8682(b) shall be maintained.
§63.8694(d)
Records shall be maintained in accordance with the
following requirements:
In a form suitable and readily available for
expeditious review, according to §63.10(b)(1) of
Subpart A
§63.8695(a)
Any records required to be maintained by this
subpart that are submitted electronically via EPA’s
CEDRI may be maintained in electronic format.
§63.8694(e)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
Keep for a period of five (5) years following the date
of each occurrence, measurement, maintenance,
corrective action, report, or records as specified in
§63.10(b)(1) of Subpart A.
§63.8695(b)
You must keep each record on site for at least 2
years after the date of each occurrence,
measurement, maintenance, corrective action,
report, or record, according to §63.10(b)(1) of
Subpart A. You can keep the records offsite for the
remaining 3 years.
§63.8695(c)
The following reports shall be submitted to demonstrate
compliance with the Asphalt MACT:
A Compliance Report shall be submitted according
to the following requirements:
§63.8693(a), (e)
Table 6, No. 5
(i) The report shall include the information
specified in §63.8693(c) of the Asphalt
MACT.
§63.8693(c)
(ii) For each Deviation Event
(A) If you have a deviation from any
emission limitation (emission limit,
operating limit, opacity limit), the
report must contain the
information specified in
§63.8693(c) and (d) of the Asphalt
MACT for each deviation from an
emissions limitations.
Table 6, No. 5(c)
§63.8693(c)(5) and (d)
(B) The report shall include a
statement that there were no
deviations from the emission
limitations during the reporting
period, if there are no deviations
from any emission limitations
(emission limit, operating limit,
opacity limit)
§63.8693(c)(5)
Table 6, No. 5(a)
(iii) For each Excess Emission event
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
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(A) If there were periods during which
the continuous parameter
monitoring system (CPMS) was out-
of-control, as specified in
§63.8(c)(7) of Subpart A, the report
must contain the information
specified in §63.8693(d) of the
Asphalt MACT
§63.8693(b), (d)
Table 6, No. 5(c)
(B) The report shall include a
statement if there were no periods
during which the CPMS was out-of-
control as specified in §63.8(c)(7) of
Subpart A, that there were no
periods during which the CPMS was
out-of-control during the reporting
period
§63.8693(b), (c)(6)
Table 6, No. 5(b)
(iv) Before September 9, 2020, the compliance
report shall include the information below
for each startup, shutdown, or malfunction
event. After this date, these requirements
no longer apply.
(A) If you had a startup, shutdown, or
malfunction during the reporting
period and actions consistent with
the startup, shutdown, and
malfunction plan (SSMP) were
taken, the compliance report must
include the information in
§63.10(d)(5)(i) of Subpart A.
§63.8685(c)
§63.8693(c)(4)
Table 6, No. 5(d)
(B) If you had a startup, shutdown, or
malfunction during the reporting
period and actions not consistent
with the SSMP were taken, the
compliance report must include the
information specified in
§63.10(d)(5)(ii) of Subpart A.
Table 6, No. 6
(v) Each Compliance Report shall cover a semi-
annual reporting period and shall be
submitted according to the following
reporting schedule:
§63.8693(b)(1)-(3), (5), (e)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
Reporting Period Submittal Date
January 1- June 30 August 28
July 1- December 31 February 28
(vi) On or after September 9, 2020, all
Compliance Reports shall be submitted to
EPA via the CEDRI.
§63.8693(b)(6)
An immediate SSM Report shall be submitted
according to the following requirements:
Table 6, No. 6
(i) During the reporting period before
September 9, 2020, each startup,
shutdown or malfunction event occurring
in which actions taken were not consistent
with the SSMP shall be submitted by fax or
telephone within 2 working days after
starting actions inconsistent with the plan
followed by a letter within 7 working days
after the end of the event unless you have
made alternative arrangements with the
Department.
(ii) On or after September 9, 2020, this
requirement no longer applies.
(3) On or after September 9, 2020, a performance test
report, including information in §63.7, shall be
submitted, within 60 days after the date of
completion of each performance test except as
allowed under §63.8693(h) or (i), in accordance to
the following procedures:
§63.8693(f), (h), (i)
(i) For test data collected using test methods
supported by EPA’s Electronic Reporting
Tool (ERT) at the time of the test, the
results of testing must be submitted to the
EPA via CEDRI as specified.
§63.8693(f)(1)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
(ii) For test data collected using test methods
NOT supported by EPA’s ERT at the time of
the test, the results of the performance test
must be included as an attachment in the
ERT or alternate electronic file consistent
with the XML schema listed on EPA’s ERT
website. The ERT generated package or
alternative file must be submitted to EPA
via CEDRI as specified.
§63.8693(f)(2)
(iii) For data claimed to be Confidential
Business Information (CBI), the
requirement specified in §63.8692(e) and
§63.8693(f)(3) shall be met.
§63.8692(e)
§63.8693(f)(3)
(iv) Notification of report submittals via CEDRI
must also be provided to the Department.
(4) On or after September 9, 2020, the results of each
performance evaluation (as defined in §63.2)
conducted on a continuous monitoring system
(CMS), must be submitted within 60 days after the
date of completion of each evaluations in
accordance to the procedures specified in
§63.8693(g).
§63.2
§63.8693(g)
(i) For performance evaluations of CMS
measuring RATA pollutants that are
supported by EPA’s ERT at the time of the
evaluation, the results of the performance
evaluation must be submitted to the EPA
via CEDRI as specified.
§63.8693(g)(1)
(ii) For performance evaluations of CMS
measuring RATA pollutants that are NOT
supported by EPA’s ERT at the time of the
evaluation, the results of the performance
evaluation must be included as an
attachment in the ERT or alternate
electronic file consistent with the XML
schema listed on EPA’s ERT website. The
ERT generated package or alternative file
must be submitted to EPA via CEDRI as
specified.
§63.8693(g)(2)
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Provisos for Asphalt Processing Facilities & Thermal Oxidizer
Federally Enforceable Provisos Regulations
(iii) For data claimed to be CBI, the requirement
specified in §63.8692(e) and §63.8693(g)(3)
shall be met.
§63.8692(e)
§63.8693(g)(3)
(iv) Notification of report submittals via CEDRI
must also be provided to the Department.
Each deviation from the requirements specified in this subpart,
including those that occur during startups, shutdowns, and
malfunctions, shall be reported to the Department in a manner that
complies with proviso 15(b) and 21(b) of the General Provisos
subpart of this permit.
Rule 335-3-16-.05(c)3(ii)
§60.105(e)(3)(ii)
§63.8693(e)
245
Summary Page for Petroleum Coke Drying and Pulverizing Systems
Permitted Operating Schedule: 24 Hours/Day x 365 Days/Year = 8,760 Hours/Year †Except during leap year, Permitted Operating Schedule = 8,784 Hours/Year
Emission limitations:
Emission
Point
Description Pollutant Emission
Limit/Standard
Regulations
PETROLEUM COKE PULVERIZING SYSTEM
For charge rate [P] < 30 Ton/hr
OR
Particulate [3.59] X [P]^ 0.62 Rule 335-3-4-.04(1)
For charge rate [P] ≥ 30 Ton/hr
OR
Particulate [17.31] X [P]^ 0.16 Rule 335-3-4-.04(1)
Otherwise Particulate Emissions from the baghouse
vent shall not exceed
3.0 Lb/hr
Rule 335-3-14-.04
[Anti-PSD Limit]
Opacity No more than one 6 min avg. >
20%
Rule 335-3-4-.01(1)(a)
OR
No 6 min avg. > 40% in any sixty
(60) minute period Rule 335-3-4-.01(1)(b)
INDIVIDUAL SOURCES:
FEED SILO
DRYING/PULVERIZING MILL WITH BAGHOUSE
PRODUCT SILO WITH BIN VENT FILTER
TRUCK LOADING BAY
246
Provisos for Petroleum Coke Drying and Pulverizing Systems
Federally Enforceable Provisos Regulations
Applicability
The petroleum coke drying and pulverizing system shall comply with the
requirements specified in ADEM Admin. Code r. 335-3-4-.01(1)(a) and (b),
“Visible Emissions”, and specified in ADEM Admin. Code r. 335-3-4-.04(1),
“Process Industries-General” for Control of Particulate Emissions and the
requirements specified in this subpart of this permit.
Rule 335-3-4-.01(1)(a) and (b)
Rule 335-3-4-.04(1)
The petroleum coke drying and pulverizing system shall be subject to the
requirements specified in ADEM Admin. Code r. 335-3-16, “Major Source
Operating Permits”, and the requirements specified in this subpart of this
permit.
Rule 335-3-16-.03
The petroleum coke drying and pulverizing system has enforceable limits in
place in order to avoid a review under ADEM Admin. Code r. 335-3-14-.04,
“Air Permits Authorizing Construction in Clean Air Areas [Prevention of
Significant Deterioration (PSD)] and the requirements specified in this
subpart of this permit.
Rule 335-3-14-.04
[Anti-PSD Limit]
The baghouse shall be subject to the requirements specified in 40 CFR Part
64, “Compliance Assurance Monitoring” [CAM], proviso 33 of the “General
Permit Provisos” subpart of this permit and this subpart of this permit.
40 CFR Part §64
Emission Standards
Visible emissions from the baghouse shall meet the opacity standards
specified in proviso 1(a) and (b) of this section of this subpart.
Rule 335-3-4-.01(a), (b)
The unit shall not discharge into the atmosphere particulate that
results in an opacity greater than 20%, as determined by a 6-minute
average.
Rule 335-3-4-.01(1)(a)
Except for one 6-minute period during any 60-minute period, the
unit shall not discharge into the atmosphere particulate that results
in an opacity greater than 40%.
Rule 335-3-4-.01(1)(b)
Particulate matter (PM10) emissions from the petroleum coke drying and
pulverizing system shall not exceed the allowable specified in either proviso
2(a) or (b) or (c) of this section of this subpart.
Rule 335-3-16-.05(a)
Provided the charge rate is less than 30 Tons/Hour, the allowed
emissions shall be calculated as follows:
Rule 335-3-4-.04(1)
PM10 <= [3.59] X [Charge Rate (Tons/Hour)]0.62
247
Provisos for Petroleum Coke Drying and Pulverizing Systems
Federally Enforceable Provisos Regulations
Provided the charge rate is equal to or greater than 30 Tons/Hour,
the allowed emissions shall be calculated as follows:
Rule 335-3-4-.04(1)
PM10 <= [17.31] X [Charge Rate (Tons/Hour)]0.16
PM10 emissions from the baghouse vent shall not exceed 3.0
pounds per hour (Lb/hr)
Rule 335-3-14-.04
[Anti-PSD Limit]
The petroleum coke drying and pulverizing system shall meet the
requirements specified in proviso (a) through (d) of this section of this
subpart.
Rule 335-3-14-.04
[Anti-PSD Limit]
Each conveying system within the dryer/pulverizing system shall be
a closed conveying system.
The drying/pulverizing mill shall be enclosed on all sides with
outlets provided for each conveying system.
Emissions from the dryer/pulverizing mill shall be captured and sent
to the baghouse for the removal of particulate matter.
A weekly inspection of the petroleum coke drying/pulverizing
system shall be undertaken to assure proper operations. All pieces
of equipment found to be operating improperly shall be repaired or
replaced at the earliest possible time.
Compliance and Performance Test Methods and Procedures
Compliance with the opacity standards for the petroleum coke
drying/pulverizing system shall be determined using Method 9 or Method
22 of 40 CFR Part 60, Appendix A.
Rule 335-3-1-.05
Rule 335-3-4-.01(2)
A performance test shall be conducted on the baghouse in accordance with
the following methods and procedures:
Rule 335-3-16-.05(c)(1)(i)
Rule 335-3-14-.04
[Anti-PSD Limit]
(a) Method 1 or 1A, of 40 CFR Part 60, Appendix A to determine sample
and velocity traverses
(b) Method 2 or 2A or 2B or 2C or 2D of 40 CFR Part 60, Appendix A to
determine volumetric flow rates
(c) Method 3 or 3A or 3B or 3C of 40 CFR Part 60, Appendix A to
determine oxygen emissions
248
Provisos for Petroleum Coke Drying and Pulverizing Systems
Federally Enforceable Provisos Regulations
(d) Method 4 of 40 CFR Part 60, Appendix A to determine the moisture
content in stack gases
(e) Method 5 of 40 CFR Part 60, Appendix A to determine PM emissions
(f) The methods and procedures that are utilized may be modified
upon receiving Departmental approval.
Emission Monitoring
CAM and opacity monitoring shall be conducted as specified in Appendix F:
Petroleum Coke Drying & Pulverizing System of this.
§64.3
§64.6(b)
A performance test shall be conducted on the baghouse in accordance with
the following requirements:
Rule 335-3-16-.05(c)(1)(i) & (ii)
Rule 335-3-14-.04
[Anti-PSD Limit]
The test shall consist of three runs of at least 1-hour in duration
Each run shall test for PM10 emissions
The pollutants tested for may be modified upon receiving
Departmental approval.
Subsequent performance tests shall be conducted on the baghouse
at least once every five (5) years
Recordkeeping and Reporting Requirements
A record of the information specified in provisos 1(a) through (f) of this
section of this subpart shall be maintained and made available for
inspection.
Rule 335-3-16-.05(c)(2)
§64.9
The date, starting time, and duration of each deviation from the
requirements specified in this subpart along with the cause and
corrective actions taken
The date, time, and results of each performance tests along with
any other tests conducted on the baghouse that provides additional
stack pollutant content data
The date and time of each shut down and startup of the petroleum
coke drying/pulverizing system
Date and type of maintenance that affects air emissions
Results of each visual emission observation
249
Provisos for Petroleum Coke Drying and Pulverizing Systems
Federally Enforceable Provisos Regulations
Continuous monitoring and daily visible inspection records
A periodic monitoring report (PMR) meeting the requirements specified in
proviso 2(a) and (b) of this section of this subpart shall be submitted to the
Department.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(i)
Each report shall identify each incidence of deviation from a permit
term or condition including those that occur during startups and
shutdowns.
A deviation shall mean any condition determined by
observation, by data derived from any monitoring or
testing or recordkeeping which is required by the permit
that can be used to determine or indicate compliance, that
identifies an affected source has failed to meet an
applicable emission limit or standard, or that a work
practice was not complied with or completed.
If no deviation event occurred during the reporting period,
a statement that indicates there were no deviations from
the permit requirements shall be included in the report.
Except as provided for in proviso 2(c) of this section, the report shall
include the information specified in proviso 2(b)(1) of this section
of this subpart.
For each deviation event, the following information shall be
submitted:
(i) Emission source description
(ii) Permit requirement
(iii) Date
(iv) Starting time
(v) Duration
(vi) Actual quantity of pollutant or parameter
(vii) Cause
(viii) Actions taken to return to normal operating
conditions
250
Provisos for Petroleum Coke Drying and Pulverizing Systems
Federally Enforceable Provisos Regulations
(ix) Total operating hours of the affected source during
the reporting period
(x) Total hours of deviation events during the
reporting period
(xi) Total hours of deviation events that occurred
during startups, shutdowns, and malfunctions
during the reporting period
Each report shall cover a calendar semi-annual period and shall be submitted
according to the following reporting schedule:
Reporting Period Submittal Date
January 1 - June 30 August 28
July 1 - December 31 February 28
The report content specified in proviso 2(b) of this section
may be modified upon receipt of Departmental approval.
Each deviation from the requirements specified in this subpart, including
those that occur during startups, shutdowns, and malfunctions, shall be
reported to the Department in a manner that complies with proviso 15(b)
and 21(b) of the general proviso subpart of this permit.
Rule 335-3-16-.05(c)(2)
Rule 335-3-16-.05(c)(3)(ii)
251
APPENDIX A: HEATERS & BOILERS MONITORING
252
HEATING UNITS SUBJECT TO NOX TESTING
Monitoring approach: Periodic Monitoring
I. Indicator Calculate NOX Emissions for Pre-Black Warrior Heaters: H-501 and common stacks for H-700/H-701, BA-601M/BA-
602M, HS-2041A/B/C Calculate NOX Emissions for Pre-Black Warrior Boilers: B-04 & B-06
A. Measurement approach Fuel gas volume to each unit shall be monitored with a system capable of measuring and recording the flow rate
and/or the parameters utilized for flow rate calculation
BTU content of fuel gas stream shall be determined monthly, or at a frequency determined by the Department
Pollutant emission factors shall be determined during performance tests
II. Indicator range NOX emissions shall be maintained at less than, or equal to, the limit specified in the Emission Standards subpart
of the Pre- Black Warrior Expansion Units: Process Heaters & Boilers section of this permit
A deviation is defined as anytime the calculated emission rate exceeds the respective allowed emission rates
A deviation triggers an immediate inspection, corrective action, and reporting within 48 hours or two workdays.
A. QIP threshold Not applicable
III. Performance criteria
A. Data representiveness Fuel gas volume monitor shall be located immediately upstream of each unit.
Fuel gas BTU content shall be determined from samples that are representative of the fuel gas being consumed.
Performance tests shall be undertaken while each unit is being operated at normal loads.
B. Verification of operational status Not applicable
C. QA/QC practices & criteria The fuel gas volume monitor shall be calibrated at a frequency in accordance with the manufacturer’s
specifications, other written procedures that provide adequate assurance that the device is calibrated accurately, or
at least annually whichever is more frequent.
253
HEATING UNITS SUBJECT TO NOX TESTING
Monitoring approach: Periodic Monitoring
If the fuel gas monitor fails its calibration tests, the fuel gas monitor shall be taken out of service until repairs
and/or replacements are made and a new calibration test is undertaken and passed.
D. Monitoring frequency Fuel gas volume measured continuously.
Fuel gas BTU content shall be determined monthly, or at a frequency set by the Department.
Performance tests shall be undertaken every 5 years.
Data collection procedure Calculate: Monthly, or as set by the Department,
Pollutant emissions while utilizing the fuel volume, BTU content, emission factor and operating hours
Fuel gas volume consumed
Record: Monthly, or as set by the Department
Fuel gas volume consumed
Hours of operation
Pollutant emissions
Record: Each occurrence
Each fuel gas BTU content determination
Time, date, and results of each inspection and corrective actions taken
Averaging period Monthly, or as set by the Department
254
HEATING UNITS SUBJECT TO VOC TESTING
Monitoring approach: Periodic Monitoring
I. Indicator Calculate VOC Emissions for Black Warrior Heaters: HP2-H-3600, BA-603 and common stacks for HD-H-3401/HD-H-
3402 and for CR-H-3801/ CR-H-3802/ CR-H-3803
A. Measurement approach Fuel gas volume to each unit shall be monitored with a system capable of measuring and recording the flow rate
and/or the parameters utilized for flow rate calculation
BTU content of fuel gas stream shall be determined monthly, or at a frequency determined by the Department
Pollutant emission factors shall be determined during performance tests
II. Indicator range VOC emissions shall be maintained at less than, or equal to, the limit specified in the Emission Standards subpart
of the Black Warrior Expansion Units: Process Heaters section of the permit
A deviation is defined as anytime the calculated emission rate exceeds the respective allowed emission rates
A deviation triggers an immediate inspection, corrective action, and reporting within 48 hours or two workdays.
A. QIP threshold Not applicable
III. Performance criteria
A. Data representiveness Fuel gas volume monitor shall be located immediately upstream of each unit.
Fuel gas BTU content shall be determined from samples that are representative of the fuel gas being consumed.
Performance tests shall be undertaken while each unit is being operated at normal loads.
B. Verification of operational status Not applicable
C. QA/QC practices & criteria The fuel gas volume monitor shall be calibrated at a frequency in accordance with the manufacturer’s
specifications, other written procedures that provide adequate assurance that the device is calibrated accurately, or
at least annually whichever is more frequent.
255
HEATING UNITS SUBJECT TO VOC TESTING
Monitoring approach: Periodic Monitoring
If the fuel gas monitor fails its calibration tests, the fuel gas monitor shall be taken out of service until repairs
and/or replacements are made and a new calibration test is undertaken and passed.
D. Monitoring frequency Fuel gas volume measured continuously.
Fuel gas BTU content shall be determined monthly, or at a frequency set by the Department.
Performance tests shall be undertaken every 5 years.
Data collection procedure Calculate: Monthly, or as set by the Department,
Pollutant emissions while utilizing the fuel volume, BTU content, emission factor and operating hours
Fuel gas volume consumed
Record: Monthly, or as set by the Department
Fuel gas volume consumed
Hours of operation
Pollutant emissions
Record: Each occurrence
Each fuel gas BTU content determination
Time, date, and results of each inspection and corrective actions taken
Averaging period Monthly, or as set by the Department
256
HEATING UNITS WITH NOX CEMS
Monitoring approach: Periodic Monitoring
I. Indicator A NOx CEMS shall be installed on Pre-Black Warrior Heater H-501X and Post Black Warrior Heaters: HP2-H-3600,
BA-603, HD-H-3401/HD-H-3402and CR-H-3801/ CR-H-3802/ CR-H-3803
A. Measurement approach The effluent stream shall be monitored with a system capable of continuously analyzing it for its oxygen and nitrogen
oxide (NOX) content and making appropriate calculations for each monitoring cycle and each hour and each rolling
24-hour period while recording relevant information and calculation results.
II. Indicator range NOX content shall be maintained at less than, or equal to, the amount specified in the Emission Standards subpart
of the applicable Heaters & Boilers section of the permit @ 0% excess air
For all heating units, except H-501X, an exceedance is defined as anytime the 30-day rolling average NOX
concentration is > the permitted limit.
For H-501X, an exceedance is defined as anytime the 365-day rolling average NOX concentration is > the permitted
limit
An exceedance triggers an immediate inspection and corrective actions and reporting within 48 hours or two
workdays.
A. QIP threshold Not Applicable
III. Performance criteria
A. Data representiveness Each effluent sensor shall be located at a point within the heater stack, or at a representative point for heaters sharing
a common stack that would result in the monitoring of all of the gases exiting the heater stack.
Each content sensor shall meet specifications required in:
40 CFR 60.13 (applicable to CEMS) for Heater H-501X, §60.107a(c)(1)-(5) for Heaters: BA-603, CR-H-3801/CR-H-
3802/CR-H-3803, HP2-H-3600, & HD-H-3401/HD-H-3402
B. Verification of operational status Not Applicable
C. QA/QC practices & criteria A program for the effluent continuous emission monitoring system shall be developed and implemented that meets
the requirements specified in the following regulations:
40 CFR 60.13 (applicable to CEMS) and Part 60 Appendices A and F and the applicable performance specification (PS)
of 40 CFR Part 60 for Heater H-501X; §60.107a(c)(1)-(5) for Heaters: BA-603, CR-H-3801/CR-H-3802/CR-H-3803, HP2-
H-3600, & HD-H-3401/HD-H-3402
257
HEATING UNITS WITH NOX CEMS
Monitoring approach: Periodic Monitoring
D. Monitoring frequency Effluent content shall be measured continuously
Data collection procedure For all heating units other than H-501X, calculate and record daily and rolling 30-days averages of the NOX
concentration.
For H-501X, calculate and record daily and rolling 365-day averages of the NOX concentration
Record time, date and results of each calibration
Record time, date and results of each inspection and corrective action
Averaging period For all heating units other than H-501X: Daily and rolling 30-days
For H-501X: One day and rolling 365-days
258
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259
APPENDIX B: GASOLINE LOADING RACK AND VAPOR COMBUSTOR UNIT
GASOLINE LOADING RACK & VAPOR COMBUSTOR UNIT MONITORING
Periodic Monitoring Periodic Monitoring
Opacity Vapor combustor unit firebox temperature
Provided the vapor combustor is being operated and facility operating
personnel notice visible emissions being emitted from the vapor
combustor, a daily visual emission observation on the vapor combustor
shall be undertaken.
Firebox shall be monitored with system capable of
continuously measuring the fire box temperature and
making appropriate calculations for each monitoring cycle
and each hour and three-hour period while recording
relevant information and calculation results.
Duration of each observation shall be:
>= 15 minutes AND <= 120 minutes
Each observation shall be conducted with either”
Test Method 9 of 40 CFR Part 60,
OR
Test Method 22 of 40 CFR Part 60,
No more than one 6-min. average opacity reading shall exceed 20% Firebox temperature shall be maintained at => that which
was established during latest performance test which
showed compliance with the limits.
-OR-
No 6-min. average opacity reading shall exceed 40%
-OR-
The accumulated time of observed visible emissions shall not exceed
12 minutes.
A deviation is defined as anytime the observed 6-minute average
opacity exceeds 20% for the2nd time when utilizing Method 9.
An excursion is defined as anytime the three-hour average
firebox temperature is < that which was established during
the latest performance test, conducted every two years, for
which the standard was met
A deviation is defined as anytime the observed 6-minute average
opacity exceeds 40% for the 1st time when utilizing Method 9.
An excursion triggers an immediate inspection and
corrective actions and reporting within 48 hours.
261
GASOLINE LOADING RACK & VAPOR COMBUSTOR UNIT MONITORING
Monitoring approach: Periodic Monitoring Periodic Monitoring I. Indicator Opacity Vapor combustor unit firebox temperature
A deviation is defined as anytime the accumulated time in which
visible emissions were observed exceeds 12 minutes per observation
when utilizing Method 22.
The minimum firebox temperature may be modified upon
receipt of Departmental approval.
A deviation triggers continued visible emissions observations at a
frequency suitable to defining the duration of the visible emission
deviation event. One observation shall be undertaken to establish the
end of the visible emission deviation event.
A QIP threshold Not applicable If the accumulated hours of excursion events occurring
exceeds 5% of the vapor combustor operating time during
any quarterly reporting period, a Quality Improvement Plan
shall be developed and implemented.
III. Performance criteria
A. Data representiveness Each temperature sensor shall be located within the vapor
combustor unit combustion chamber or immediately
downstream of the combustion chamber.
B. Verification of operational Not applicable
status
C. QA/QC practices & criteria A program for the firebox continuous emissions
monitoring system shall be developed and implemented
that meets the requirements specified in §63.427
If the sensor fails its calibration test, the sensor shall be
taken out of service until repairs and/or replacements are
made and a new calibration test is undertaken and passed.
262
GASOLINE LOADING RACK & VAPOR COMBUSTOR UNIT MONITORING
Monitoring approach: Periodic Monitoring Periodic Monitoring I. Indicator Opacity Vapor combustor unit firebox temperature
D. Monitoring frequency Daily Temperature shall be measured continuously.
Data collection procedure Record: Daily Record hourly firebox temperature.
Each 15 second observation reading
Record calibration results
Record: Each occurrence
Time, date and results of corrective actions taken Record inspection results and corrective actions taken.
Averaging period Six minutes Hour
263
APPENDIX C: SULFUR RECOVERY SYSTEMS’ THERMAL OXIDIZER
264
EACH SULFUR RECOVERY SYSTEMS’ THERMAL OXIDIZER
Monitoring approach: Compliance Assurance Monitoring [CAM]
I. Indicator Operate thermal oxidizer with a flame or spark present at all times when a process gas stream
may be sent to it.
A. Measurement approach The thermal oxidizer shall be equipped either with a continuous sparking flame igniter
that is monitored by an amp meter or an equivalent device or visual observation
OR
with a continuously burning pilot light that is monitored with either a thermocouple or an
equivalent device or by visual observation.
II. Indicator range Presence of a flame or spark at burner tip
A deviation is defined as when there was no spark or flame present at the burner tip when a
process gas stream could be vented to it.
A deviation triggers an immediate inspection and corrective actions that meet the requirements
of 40 CFR Part §64.7(d) and reporting within 48 hours or two workdays.
A QIP threshold If the accumulated hours of deviation events occurring exceeds 5% of the thermal oxidizer’s
operating time during any quarterly reporting period, a Quality Improvement Plan shall be
developed and implemented.
III. Performance criteria
A. Data representiveness Each flame igniter or flame monitor shall be located at the burner tip and focused on the area
where gas exits the burner.
Visual observations shall be made from the location that provides the best view of the burner
pilot lights or burner igniter.
B. Verification of operational status Not applicable
C. QA/QC practices & criteria Each flame igniter or flame monitor shall be maintained and calibrated in accordance with the
manufacturer’s specifications, other written procedures that provide adequate assurance that
the device is properly maintained and calibrated accurately, or at least annually whichever is
more frequent.
Repairs and/or replacements shall be made immediately when non-functioning or damaged
parts are found.
Flame igniter arc length shall not exceed 10% of arc interval and shall have an arcing frequency
of no greater than once every 3 seconds.
D. Monitoring frequency Pilot flame shall be monitored either continuously with a thermocouple or daily with visual
inspections if operating staff is on site.
Flame igniter – arcing frequency shall be monitored either continuous with an amp meter or
daily with visual inspections if operating staff is on site.
Data collection procedure Record time, date and duration of each incident of when no spark or flame was present at the
flare tip when a process gas stream could have been sent to it
Record time, date and results of each visual observation
Record time, date and results of each calibration
Record time, date and results of each inspection and corrective action
Averaging period Instantaneous
265
APPENDIX D: FACILITY FLARE MONITORING
266
FACILITY FLARE MONITORING
Monitoring approach: Periodic Monitoring
I. Indicator Assist gas to acid gas volume ratio
A. Measurement approach Inlet assist gas and acid gas feed volume shall be monitored with a system capable of
measuring and recording the flow rate and/or the parameters utilized for flow rate
calculation or estimated utilizing material balances, computer simulations, special testing,
or other approved methods.
II. Indicator range Assist gas to acid gas volume ratio shall be equal or greater than 0.5 to 1.0.
A deviation is defined as anytime the actual ratio is less than 0.5 to 1.0.
If the total duration of deviation hours during a quarterly reporting period exceeds 5% of an
emergency flare’s operating time, an air quality modeling study that utilizes the maximum
inlet mass and flow rates shall be performed.
The minimum ratio may be modified upon receipt of Departmental approval.
A QIP threshold Not applicable
III. Performance criteria
A. Data representiveness Each volume monitor shall be located upstream of the flare and shall consist of a single
device that monitors all streams or multiple devices that monitor individual or multiple
streams.
B. Verification of Not applicable
operational status
267
APPENDIX E: ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER
MONITORING
268
ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER
Monitoring approach: Periodic Monitoring Periodic Monitoring
I. Indicator Thermal oxidizer combustion zone temperature Opacity
A. Measurement approach Exhaust from each blowing still must be routed to the
thermal oxidizer and the thermal oxidizer’s combustion
zone shall be monitored with system capable of
continuously measuring the combustion zone
temperature and making appropriate calculations for
each monitoring cycle and each hour and three hour
period while recording relevant information and
calculation results.
[Table 5, No. 1(a)(i), §63.8688(a), (b), §63.8690(b),(c) of
Asphalt MACT]
Provided the thermal oxidizer is being operated and facility operating
personnel notice visible emissions being emitted from the thermal
oxidizer, a daily visual emission observation on the thermal oxidizer
shall be undertaken.
Duration of each observation shall be
>= 15 minutes
AND
<= 120 minutes
Each observation shall be conducted in accordance with either:
Test Method 9 of 40 CFR Part 60, Appendix A
-OR-
Test Method 22 of 40 CFR Part 60, Appendix A
A deviation is defined as anytime the three hour
average combustion zone temperature is < that which
was established during latest performance test.
[§63.8684(b), §63.8691(b), (d)]
A deviation is defined as anytime the observed 6-minute average
opacity exceeds 20% for the 2nd time when utilizing Method 9.
II. Indicator range Combustion zone temperature shall be maintained at No more than one 6-min. average opacity reading shall exceed 20%
-OR-
No 6-min. average opacity reading shall exceed 40%.
-OR-
The accumulated time of observed visible emissions shall not exceed
12 minutes.
=> that which was established during latest
performance test which showed compliance with the
limits [§63.8691(a), (e)]].
A deviation is defined as anytime the observed 6- minute average
opacity exceeds 40% for the 1st time when utilizing Method 9.
269
ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER
Monitoring approach: Periodic Monitoring Periodic Monitoring
I. Indicator Thermal oxidizer combustion zone temperature Opacity
An excursion triggers an immediate inspection and
corrective actions and reporting within 48 hours
A deviation is defined as anytime the accumulated time in which visible
emissions were observed exceeds 12 minutes per observation when
utilizing Method 22.
A deviation triggers continued visible emissions observations at a
frequency suitable to defining the duration of the visible emission
deviation event. One observation shall be undertaken to establish the
end of the visible emission deviation event.
The minimum combustion zone temperature shall be
established during each performance test required by
§63.8687(a) [Table 5, No. 1(a)(iv), Asphalt MACT]..
A QIP threshold Not applicable Not applicable
III. Performance criteria
A. Data representiveness Each temperature sensor shall be located within the
thermal oxidizer combustion chamber or immediately
downstream of the combustion chamber.
[§63.8688(b)(1)]
Each temperature sensor shall meet specifications
required in §63.8688(a), (b), & Table No. 5 of the
Asphalt MACT
B. Verification of operational status The requirements specified in §63.8688(b)(4), (5), (6)
and (i) of the Asphalt MACT shall be met.
270
ASPHALT PROCESSING FACILITY & THERMAL OXIDIZER
Monitoring approach: Periodic Monitoring Periodic Monitoring
I. Indicator Thermal oxidizer combustion zone temperature Opacity
C. QA/QC practices & criteria A program for the combustion zone temperature
continuous emissions monitoring system shall be
developed and implemented that meets the
requirements specified in the following regulations:
§63.8688(g) & (h)
Table No. 5, Asphalt MACT
If the sensor fails its calibration test, the sensor shall be
taken out of service until repairs and/or replacements
are made and a new calibration test is undertaken and
passed.
D. Monitoring frequency Temperature shall be measured continuously. Daily
Data collection procedure Record hourly and three-hour average combustion
zone temperature [§63.8688(a)]
Record calibration results. Record: Daily
Each 15 second observation reading
Record inspection results and corrective Record: Each occurrence
actions taken.
Time, date and results of corrective actions taken
Averaging period Three hours [Table 5, Item 1(a)(iii), Asphalt MACT] Six minutes
271
APPENDIX F: PETROLEUM COKE DRYING & PULVERIZING SYSTEM
272
PETROLEUM COKE DRYING & PULVERIZING SYSTEM
Monitoring approach: Compliance Assurance Monitoring [CAM] Compliance Assurance Monitoring [CAM]
I. Indicator Pressure drop Visible emissions
A. Measurement approach Pressure drop across baghouse shall be monitored with
system capable of continuously measuring the inlet and
outlet baghouse pressure, calculating the pressure drop
for each monitoring cycle and each hour while recording
all relevant information and calculation results.
Provided the dryer/pulverizing mill is being operated, a
daily visual emissions observation on the baghouse shall be
undertaken.
Duration of each observation shall be:
>= 15 minutes AND <= 120 minutes
Each observation shall be conducted in accordance
with either:
Test Method 9 of 40 CFR Part 60,
Or
Test Method 22 of 40 CFR Part 60,
II. Indicator range Actual pressure shall be maintained within ± 50% of The accumulated time of observed visible emissions
the pressure drop established during latest performance
test.
An excursion is defined as anytime the pressure drop does
not fall into the established range.
An excursion triggers continued pressure drop readings at
a frequency suitable to defining the duration of the
pressure drop deviation event.
Two readings three hours apart shall be undertaken to
establish the end of the deviation event.
An excursion triggers an immediate inspection, corrective
action and reporting within 48 hours or two workdays.
shall not exceed 5 minutes during any two hour period.
An excursion is defined as anytime the accumulated time
of opacity observed exceeds 5 minutes during any
observation while utilizing either Method 9 or 22.
An excursion triggers continued visible emissions
observations at a frequency suitable to defining the
duration of the visible emission deviation event.
One observation shall be undertaken to establish the end
of the visible emission deviation event. An excursion
triggers an immediate inspection, corrective action and
reporting within 48 hours or two workdays.
273
PETROLEUM COKE DRYING & PULVERIZING SYSTEM
Monitoring approach: Compliance Assurance Monitoring [CAM] Compliance Assurance Monitoring [CAM]
I. Indicator Pressure drop Visible emissions
The pressure drop range may be modified upon receipt of
Department approval.
A QIP threshold If the accumulated hours of excursion events occurring
exceeds 5% of the dryer/pulverizing mill’s operating time
during any quarterly reporting period, a Quality
Improvement Plan shall be developed and implemented.
If the accumulated hours of excursion events occurring
exceeds 5% of the dryer/pulverizing mill’s operating time
during any quarterly reporting period, a Quality
Improvement Plan shall be developed and implemented.
III. Performance criteria
A. Data representiveness Pressure taps shall be located at the baghouse inlet and
outlet.
Observations shall be performed at the baghouse exhaust
while the dryer/pulverizing mill is operating.
B. Verification of operational Not applicable Not applicable
status
C. QA/QC practices & criteria Calibrate, maintain and operate the monitoring system
using the procedures that take into account
manufacturer’s specification.
Observations shall be performed by individuals familiar
with Method 9 &/or 22 and shall follow those procedures.
D. Monitoring frequency Continuous Daily
Observation frequency may be changed upon receiving
Departmental approval.
Observation frequency may be changed upon receiving
Departmental approval.
Data collection procedure Record hourly pressure drop Record: Daily
Each 15 second observation reading
Record: Each occurrence Record: Each occurrence
Time, date and results of corrective actions Time, date and results of corrective actions
taken taken
Averaging period Instantaneous Six minutes
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