Nov. 4, 2011 Redline of 40 CFR part 63, subpart CC

, showing proposed amendments

Insertions are shown in bold blue text

Delet ions are show n in red strikeout text

Title 40: Protection of Environment

PART 63

— NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS

FOR SOURCE CATEGORIES

Subpart CC

— National Emission Standards for Hazardous Air Pollutants From Petroleum

Refineries

§ 63.640 Applicability and designati on of affected source.

(a) This subpart applies to petroleum refining process units and to related emissions points that are specified in paragraphs (c)( 1 5 ) through (c) (8) of this section that are located at a plant site and that meet the criteria in parag raphs (a)(1) and (2) of this section:

(1) Are located at a plant site that is a major source as defined in section 112(a) of the Clean Air Act; and

(2) Emit or have equipment containing or contacting one or more of the hazardous air pollutants

listed in ta ble 1 of this subpart.

(b)(1) If the predominant use of the flexible operation unit, as described in paragraphs (b)(1)(i) and (ii) of this section, is as a petroleum refining process unit, as defined in §63.641, then the flexible operation unit shall be su bject to the provisions of this subpart.

(i) Except as provided in paragraph (b)(1)(ii) of this section, the predominant use of the flexible operation unit shall be the use representing the greatest annual operating time.

(ii) If the flexible operation uni t is used as a petroleum refining process unit and for another purpose equally based on operating time, then the predominant use of the flexible operation unit shall be the use that produces the greatest annual production on a mass basis.

(2) The determina tion of applicability of this subpart to petroleum refining process units that are designed and operated as flexible operation units shall be reported as specified in §63.655(h)(6)(i).

(c) For the purposes of this subpart, the affected source shall compris e all emissions points, in combination, listed in paragraphs (c)(1) through (c)(8) of this section that are located at a single refinery plant site.

(1) All miscellaneous process vents from petroleum refining process units meeting the criteria in paragraph (a) of this section;Page 2 of 107

(2) All storage vessels associated with petroleum refining process units meeting the criteria in paragraph (a) of this section;

(3) All wastewater streams and treatment operations associated with petroleum refining process

units meeti ng the criteria in paragraph (a) of this section;

(4) All equipment leaks from petroleum refining process units meeting the criteria in paragraph (a) of this section;

(5) All gasoline loading racks classified under Standard Industrial Classification code 2 911 meeting the criteria in paragraph (a) of this section;

(6) All marine vessel loading operations located at a petroleum refinery meeting the criteria in paragraph (a) of this section and the applicability criteria of subpart Y, §63.560;

(7) All storage vessels and equipment leaks associated with a bulk gasoline terminal or pipeline

breakout station classified under Standard Industrial Classification code 2911 located within a contiguous area and under common control with a refinery meeting the criteria i n paragraph (a) of this section; and

(8) All heat exchange systems associated with petroleum refining process units meeting the criteria in paragraph (a) of this section and which are in organic hazardous air pollutants (HAP)

service as defined in this sub part.

(d) The affected source subject to this subpart does not include the emission points listed in paragraphs (d)(1) through (d)(5) of this section.

(1) Stormwater from segregated stormwater sewers;

(2) Spills;

(3) Any pump, compressor, pressure relief d evice, sampling connection system, open

- ended valve or line, valve, or instrumentation system that is intended to operate in organic hazardous air pollutant service, as defined in §63.641 of this subpart, for less than 300 hours during the calendar year;

( 4) Catalytic cracking unit and catalytic reformer catalyst regeneration vents, and sulfur plant vents; and

(5) Emission points routed to a fuel gas system, as defined in §63.641 of this subpart. No testing, monitoring, recordkeeping, or reporting is requir ed for refinery fuel gas systems or emission points routed to refinery fuel gas systems.

(e) The owner or operator of a storage vessel constructed on or before August 18, 1994, shall follow the procedures specified in paragraphs (e)(1) and (e)(2) of this s ection to determine whether a storage vessel is part of a source to which this subpart applies. The owner or operatorPage 3 of 107

of a storage vessel constructed after August 18, 1994, shall follow the procedures specified in paragraphs (e)(1), (e)(2)(i), and (e)(2)(i i) of this section to determine whether a storage vessel is part of a source to which this subpart applies.

(1) Where a storage vessel is used exclusively by a process unit, the storage vessel shall be considered part of that process unit.

(i) If the proce ss unit is a petroleum refining process unit subject to this subpart, then the storage vessel is part of the affected source to which this subpart applies.

(ii) If the process unit is not subject to this subpart, then the storage vessel is not part of the affected source to which this subpart applies.

(2) If a storage vessel is not dedicated to a single process unit, then the applicability of this subpart shall be determined according to the provisions in paragraphs (e)(2)(i) through (e)(2)(iii)

of this sec tion.

(i) If a storage vessel is shared among process units and one of the process units has the predominant use, as determined by paragraphs (e)(2)(i)(A) and (e)(2)(i)(B) of this section, then the storage vessel is part of that process unit.

(A) If the gr eatest input on a volume basis into the storage vessel is from a process unit that is located on the same plant site, then that process unit has the predominant use.

(B) If the greatest input on a volume basis into the storage vessel is provided from a pro cess unit that is not located on the same plant site, then the predominant use shall be the process unit that receives the greatest amount of material on a volume basis from the storage vessel at the same plant site.

(ii) If a storage vessel is shared amon g process units so that there is no single predominant use, and at least one of those process units is a petroleum refining process unit subject to this subpart, the storage vessel shall be considered to be part of the petroleum refining process unit that is subject to this subpart. If more than one petroleum refining process unit is subject to this subpart, the owner or operator may assign the storage vessel to any of the petroleum refining process units subject to this subpart.

(iii) If the predominant us e of a storage vessel varies from year to year, then the applicability of this subpart shall be determined based on the utilization of that storage vessel during the year preceding August 18, 1995. This determination shall be reported as specified in §63.6 55(h)(6)(ii).

(f) The owner or operator of a distillation unit constructed on or before August 18, 1994, shall follow the procedures specified in paragraphs (f)(1) through (f)(4) of this section to determine whether a miscellaneous process vent from a dist illation unit is part of a source to which this subpart applies. The owner or operator of a distillation unit constructed after August 18, 1994, shall follow the procedures specified in paragraphs (f)(1) through (f)(5) of this section toPage 4 of 107

determine whether a miscellaneous process vent from a distillation unit is part of a source to which this subpart applies.

(1) If the greatest input to the distillation unit is from a process unit located on the same plant site, then the distillation unit shall be assigned to that process unit.

(2) If the greatest input to the distillation unit is provided from a process unit that is not located on the same plant site, then the distillation unit shall be assigned to the process unit located at the same plant site that receiv es the greatest amount of material from the distillation unit.

(3) If a distillation unit is shared among process units so that there is no single predominant use, as described in paragraphs (f)(1) and (f)(2) of this section, and at least one of those proc ess units is a petroleum refining process unit subject to this subpart, the distillation unit shall be assigned to the petroleum refining process unit that is subject to this subpart. If more than one petroleum refining process unit is subject to this subp art, the owner or operator may assign the distillation unit to any of the petroleum refining process units subject to this rule.

(4) If the process unit to which the distillation unit is assigned is a petroleum refining process unit subject to this subpart and the vent stream contains greater than 20 parts per million by volume total organic hazardous air pollutants, then the vent from the distillation unit is considered a miscellaneous process vent (as defined in §63.641 of this subpart) and is part of the source to which this subpart applies.

(5) If the predominant use of a distillation unit varies from year to year, then the applicability of this subpart shall be determined based on the utilization of that distillation unit during the year preceding Augus t 18, 1995. This determination shall be reported as specified in §63.655(h)(6)(iii).

(g) The provisions of this subpart do not apply to the processes specified in paragraphs (g)(1) through (g)(7) of this section.

(1) Research and development facilities, re gardless of whether the facilities are located at the same plant site as a petroleum refining process unit that is subject to the provisions of this subpart;

(2) Equipment that does not contain any of the hazardous air pollutants listed in table 1 of this subpart that is located within a petroleum refining process unit that is subject to this subpart;

(3) Units processing natural gas liquids;

(4) Units that are used specifically for recycling discarded oil;

(5) Shale oil extraction units;

(6) Ethylene proce sses; andPage 5 of 107

(7) Process units and emission points subject to subparts F, G, H, and I of this part.

(h) Except as provided in paragraphs (k), (l), or (m) of this section, sources subject to this subpart are required to achieve compliance on or before the date s specified in paragraphs (h)(1) through (h)(6) of this section.

(1) Except as provided in paragraphs (h)(1)(i) and ( ii iv ) of this section, new sources that commence construction or reconstruction after July 14, 1994, shall be in compliance with this subpa rt upon initial startup or August 18, 1995, whichever is later.

(i) [Reserved]

(ii) Heat exchange systems a A t new sources that commence construction or reconstruction after July 14, 1994 August 18, 1995 , but on or before September 4, 2007, heat exchange sys tems shall comply with the existing source requirements for heat exchange systems specified in §63.654 no later than October 29, 2012.

(iii) [Reserved]

( ii iv ) Heat exchange systems a A t new sources that commence construction or reconstruction after Septembe r 4, 2007, heat exchange systems shall be in compliance with the new source requirements in §63.654 upon initial startup or October 28, 2009, whichever is later.

(2) Except as provided in paragraphs (h)(3) through (h)(6) of this section, existing sources s hall be in compliance with this subpart no later than August 18, 1998, except as provided in §63.6(c)(5) of subpart A of this part, or unless an extension has been granted by the Administrator as provided in §63.6(i) of subpart A of this part.

(3) Marine t ank vessels at existing sources shall be in compliance with this subpart no later than August 18, 1999 unless the vessels are included in an emissions average to generate emission credits. Marine tank vessels used to generate credits in an emissions averag e shall be in compliance with this subpart no later than August 18, 1998 unless an extension has been granted by the Administrator as provided in §63.6(i).

(4) Existing Group 1 floating roof storage vessels shall be in compliance with §63.646 of this subpa rt at the first degassing and cleaning activity after August 18, 1998, or August 18, 2005,

whichever is first.

(5) An owner or operator may elect to comply with the provisions of §63.648 (c) through (i) as an alternative to the provisions of §63.648 (a) an d (b). In such cases, the owner or operator shall comply no later than the dates specified in paragraphs (h)(5)(i) through (h)(5)(iii) of this section.

(i) Phase I (see table 2 of this subpart), beginning on August 18, 1998;

(ii) Phase II (see table 2 of t his subpart), beginning no later than August 18, 1999; andPage 6 of 107

(iii) Phase III (see table 2 of this subpart), beginning no later than February 18, 2001.

(6) Heat exchange systems at an existing source shall be in compliance with the existing source

standards i n §63.654 no later than October 29, 2012.

(i) If an additional petroleum refining process unit is added to a plant site that is a major source as defined in section 112(a) of the Clean Air Act, the addition shall be subject to the requirements for a new so urce if it meets the criteria specified in paragraphs (i)(1) through (i)(3)

of this section:

(1) It is an addition that meets the definition of construction in §63.2 of subpart A of this part;

(2) Such construction commenced after July 14, 1994; and

(3) Th e addition has the potential to emit 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants.

(j) If any change is made to a petroleum refining process unit subject to this subpart, the change shall be subject to the requirements for a new source if it meets the criteria specified in paragraphs (j)(1) and (j)(2) of this section:

(1) It is a change that meets the definition of reconstruction in §63.2 of subpart A of this part;

and

(2) Such reconstruction commenced after July 14, 1994.

(k) If an additional petroleum refining process unit is added to a plant site or a change is made to a petroleum refining process unit and the addition or change is determined to be subject to the

new sou rce requirements according to paragraphs (i) or (j) of this section it must comply with the requirements specified in paragraphs (k)(1) and (k)(2) of this section:

(1) The reconstructed source, addition, or change shall be in compliance with the new source requirements upon initial startup of the reconstructed source or by August 18, 1995, whichever is later; and

(2) The owner or operator of the reconstructed source, addition, or change shall comply with the reporting and recordkeeping requirements that are applicable to new sources. The applicable reports include, but are not limited to:

(i) The application for approval of construction or reconstruction shall be submitted as soon as practical before the construction or reconstruction is planned to commence (but it need not be sooner than November 16, 1995);

(ii) The Notification of Compliance Status report as required by §63.655(f) for a new source, addition, or change;Page 7 of 107

(iii) Periodic Reports and other reports as required by §63.655(g) and (h);

(iv) Reports and notifications required by §60.487 of subpart VV of part 60 or §63.182 of subpart H of this part. The requirements for subpart H are summarized in table 3 of this subpart;

(v) Reports required by 40 CFR 61.357 of subpart FF;

(vi) Reports and notificatio ns required by §63.428(b), (c), (g)(1), (h)(1) through (h)(3), and (k) of subpart R. These requirements are summarized in table 4 of this subpart; and

(vii) Reports and notifications required by §§63.565 and 63.567 of subpart Y of this part. These requirem ents are summarized in table 5 of this subpart.

(l) If an additional petroleum refining process unit is added to a plant site or if a miscellaneous process vent, storage vessel, gasoline loading rack, marine tank vessel loading operation, or heat exchange system that meets the criteria in paragraphs (c)(1) through (8) of this section is added to an existing petroleum refinery or if another deliberate operational process change creating an additional Group 1 emissions point(s) (as defined in §63.641) is made to an existing petroleum refining process unit, and if the addition or process change is not subject to the new source requirements as determined according to paragraphs (i) or (j) of this section, the requirements in paragraphs (l)(1) through (3) of this section shall apply. Examples of process changes include, but are not limited to, changes in production capacity, or feed or raw material where the change requires construction or physical alteration of the existing equipment or catalyst type, or

whenever there is replacement, removal, or addition of recovery equipment. For purposes of this paragraph and paragraph (m) of this section, process changes do not include: Process upsets, unintentional temporary process changes, and changes that are within the eq uipment configuration and operating conditions documented in the Notification of Compliance Status report required by §63.655(f).

(1) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit are subj ect to the requirements for an existing source.

(2) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit shall be in compliance with this subpart by the dates specified in paragraphs (l)(2)(i) or (l)(2)(ii) of this section, as applicable.

(i) If a petroleum refining process unit is added to a plant site or an emission point(s) is added to any existing petroleum refining process unit, the added emission point(s) shall be in compliance upon initial startup of any added petroleum refining process unit or emission point(s) or by August 18, 1998, whichever is later.

(ii) If a deliberate operational process change to an existing petroleum refining process unit causes a Group 2 emission point to become a Group 1 emission point (as defined in §63.641), the owner or operator shall be in compliance upon initial startup or by August 18, 1998, whichever is later, unless the owner or operator demonstrates to the Administrator that achieving compliance

will take longer than making the change. If this demonstration is made to the Administrator ’ sPage 8 of 107

satisfaction, the owner or operator shall follow the procedures in paragraphs (m)(1) through (m)(3) of this section to establish a compliance date.

(3) The owner or operato r of a petroleum refining process unit or of a storage vessel, miscellaneous process vent, wastewater stream, gasoline loading rack, marine tank vessel loading operation, or heat exchange system meeting the criteria in paragraphs (c)(1) through (8)

of this section that is added to a plant site and is subject to the requirements for existing sources shall comply with the reporting and recordkeeping requirements that are applicable to existing sources including, but not limited to, the reports listed in parag raphs (l)(3)(i) through (vii) of this section. A process change to an existing petroleum refining process unit shall be subject to the reporting requirements for existing sources including, but not limited to, the reports listed in paragraphs (l)(3)(i) thr ough (l)(3)(vii) of this section. The applicable reports include, but are not

limited to:

(i) The Notification of Compliance Status report as required by §63.655(f) for the emission points that were added or changed;

(ii) Periodic Reports and other reports as required by §63.655(g) and (h);

(iii) Reports and notifications required by sections of subpart A of this part that are applicable to this subpart, as identified in table 6 of this subpart.

(iv) Reports and notifications required by §63.182, or 40 CFR 60.487. The requirements of subpart H of this part are summarized in table 3 of this subpart;

(v) Reports required by §61.357 of subpart FF;

(vi) Reports and notifications required by §63.428(b), (c), (g)(1), (h)(1) through (h)(3), and (k) of subpart R. Th ese requirements are summarized in table 4 of this subpart; and

(vii) Reports and notifications required by §§63.565 and 63.567 of subpart Y. These requirements are summarized in table 5 of this subpart.

(4) If pumps, compressors, pressure relief devices, sampling connection systems, open

- ended valves or lines, valves, or instrumentation systems are added to an existing source, they are subject to the equipment leak standards for existing sources in §63.648. A notification of compliance status report shall not be required for such added equipment.

(m) If a change that does not meet the criteria in paragraph (l) of this section is made to a petroleum refining process unit subject to this subpart, and the change causes a Group 2 emission point to become a Grou p 1 emission point (as defined in §63.641), then the owner or operator shall comply with the requirements of this subpart for existing sources for the Group 1 emission point as expeditiously as practicable, but in no event later than 3 years after the emis sion point becomes Group 1.Page 9 of 107

(1) The owner or operator shall submit to the Administrator for approval a compliance schedule, along with a justification for the schedule.

(2) The compliance schedule shall be submitted within 180 days after the change is made , unless the compliance schedule has been previously submitted to the permitting authority. If it is not possible to determine until after the change is implemented whether the emission point has become Group 1, the compliance schedule shall be submitted w ithin 180 days of the date when the affect of the change is known to the source. The compliance schedule may be submitted in the next Periodic Report if the change is made after the date the Notification of Compliance Status report is due.

(3) The Administ rator shall approve or deny the compliance schedule or request changes within 120 calendar days of receipt of the compliance schedule and justification. Approval is automatic if not received from the Administrator within 120 calendar days of receipt.

(n) O verlap of subpart CC with other regulations for storage vessels.

(1) After the compliance dates specified in paragraph (h) of this section, a Group 1 or Group 2 storage vessel that is part of an existing source and is also subject to the provisions of 40 C FR part 60, subpart Kb, is required to comply only with the requirements of 40 CFR part 60, subpart Kb, except as provided in paragraph (n)(8) of this section.

(2) After the compliance dates specified in paragraph (h) of this section a Group 1 storage vess el that is part of a new source and is subject to 40 CFR part 60, subpart Kb is required to comply only with this subpart.

(3) After the compliance dates specified in paragraph (h) of this section, a Group 2 storage vessel that is part of a new source and is subject to the control requirements in §60.112b of 40 CFR part 60, subpart Kb is required to comply only with 40 CFR part 60, subpart Kb except as provided in paragraph (n)(8) of this section.

(4) After the compliance dates specified in paragraph (h) of this section, a Group 2 storage vessel that is part of a new source and is subject to 40 CFR 60.110b, but is not required to apply controls by 40 CFR 60.110b or 60.112b is required to comply only with this subpart.

(5) After the compliance dates specified in paragraph (h) of this section a Group 1 storage vessel that is also subject to the provisions of 40 CFR part 60, subparts K or Ka is required to only comply with the provisions of this subpart.

(6) After compliance dates specified in paragraph (h) of t his section, a Group 2 storage vessel that is subject to the control requirements of 40 CFR part 60, subparts K or Ka is required to comply only with the provisions of 40 CFR part 60, subparts K or Ka except as provided for in paragraph (n)(9) of this sect ion.Page 10 of 107

(7) After the compliance dates specified in paragraph (h) of this section, a Group 2 storage vessel that is subject to 40 CFR part 60, subparts K or Ka, but not to the control requirements of 40 CFR part 60, subparts K or Ka, is required to comply onl y with this subpart.

(8) Storage vessels described by paragraphs (n)(1) and (n)(3) of this section are to comply with 40 CFR part 60, subpart Kb except as provided for in paragraphs (n)(8)(i) through (n)(8)(vi) of

this section.

(i) Storage vessels that are to comply with §60.112b(a)(2) of subpart Kb are exempt from the secondary seal requirements of §60.112b(a)(2)(i)(B) during the gap measurements for the primary seal required by §60.113b(b) of subpart Kb.

(ii) If the owner or operator determines that it is unsafe to perform the seal gap measurements required in §60.113b(b) of subpart Kb or to inspect the vessel to determine compliance with §60.113b(a) of subpart Kb because the roof appears to be structurally unsound and poses an imminent danger to inspectin g personnel, the owner or operator shall comply with the requirements in either §63.120(b)(7)(i) or §63.120(b)(7)(ii) of subpart G.

(iii) If a failure is detected during the inspections required by §60.113b(a)(2) or during the seal gap measurements require d by §60.113b(b)(1), and the vessel cannot be repaired within 45 days and the vessel cannot be emptied within 45 days, the owner or operator may utilize up to two extensions of up to 30 additional calendar days each. The owner or operator is not required t o provide a request for the extension to the Administrator.

(iv) If an extension is utilized in accordance with paragraph (n)(8)(iii) of this section, the owner or operator shall, in the next periodic report, identify the vessel, provide the information li sted in §60.113b(a)(2) or §60.113b(b)(4)(iii), and describe the nature and date of the repair made or provide the date the storage vessel was emptied.

(v) Owners and operators of storage vessels complying with subpart Kb of part 60 may submit the inspectio n reports required by §§60.115b(a)(3), (a)(4), and (b)(4) of subpart Kb as part of the periodic reports required by this subpart, rather than within the 30

- day period specified in §§60.115b(a)(3), (a)(4), and (b)(4) of subpart Kb.

(vi) The reports of rim s eal inspections specified in §60.115b(b)(2) are not required if none of the measured gaps or calculated gap areas exceed the limitations specified in §60.113b(b)(4). Documentation of the inspections shall be recorded as specified in §60.115b(b)(3).

(9) Sto rage vessels described by paragraph (n)(6) of this section that are to comply with 40 CFR part 60, subpart Ka, are to comply with only subpart Ka except as provided for in paragraphs (n)(9)(i) through (n)(9)(iv) of this section.

(i) If the owner or operato r determines that it is unsafe to perform the seal gap measurements required in §60.113a(a)(1) of subpart Ka because the floating roof appears to be structurally unsound and poses an imminent danger to inspecting personnel, the owner or operator shall

comp ly with the requirements in either §63.120(b)(7)(i) or §63.120(b)(7)(ii) of subpart G.Page 11 of 107

(ii) If a failure is detected during the seal gap measurements required by §60.113a(a)(1) of subpart Ka, and the vessel cannot be repaired within 45 days and the vessel cannot be emptied within 45 days, the owner or operator may utilize up to 2 extensions of up to 30 additional calendar days each.

(iii) If an extension is utilized in accordance with paragraph (n)(9)(ii) of this section, the owner or operator shall, in the next periodic report, identify the vessel, describe the nature and date of the repair made or provide the date the storage vessel was emptied. The owner or operator shall also provide documentation of the decision to utilize an extension including a descr iption of the failure, documentation that alternate storage capacity is unavailable, and a schedule of actions that will ensure that the control equipment will be repaired or the vessel emptied as soon as possible.

(iv) Owners and operators of storage vess els complying with subpart Ka of part 60 may submit the inspection reports required by §60.113a(a)(1)(i)(E) of subpart Ka as part of the periodic reports required by this subpart, rather than within the 60

- day period specified in §60.113a(a)(1)(i)(E) of su bpart Ka.

(o) Overlap of this subpart CC with other regulations for wastewater.

(1) After the compliance dates specified in paragraph (h) of this section a Group 1 wastewater stream managed in a piece of equipment that is also subject to the provisions of 40 CFR part 60, subpart QQQ is required to comply only with this subpart.

(2) After the compliance dates specified in paragraph (h) of this section a Group 1 or Group 2 wastewater stream that is conveyed, stored, or treated in a wastewater stream managemen t unit that also receives streams subject to the provisions of §§63.133 through 63.147 of subpart G wastewater provisions of this part shall comply as specified in paragraph (o)(2)(i) or (o)(2)(ii) of this section. Compliance with the provisions of paragra ph (o)(2) of this section shall constitute compliance with the requirements of this subpart for that wastewater stream.

(i) Comply with paragraphs (o)(2)(i)(A) through (o)(2)(i)(C) of this section.

(A) The provisions in §§63.133 through 63.140 of subpart G for all equipment used in the storage and conveyance of the Group 1 or Group 2 wastewater stream.

(B) The provisions in both 40 CFR part 61, subpart FF and in §§63.138 and 63.139 of subpart G for the treatment and control of the Group 1 or Group 2 wastewa ter stream.

(C) The provisions in §§63.143 through 63.148 of subpart G for monitoring and inspections of equipment and for recordkeeping and reporting requirements. The owner or operator is not required to comply with the monitoring, recordkeeping, and rep orting requirements associated with the treatment and control requirements in 40 CFR part 61, subpart FF, §§61.355 through

61.357.

(ii) Comply with paragraphs (o)(2)(ii)(A) and (o)(2)(ii)(B) of this section.Page 12 of 107

(A) Comply with the provisions of §§63.133 throu gh 63.148 and §§63.151 and 63.152 of subpart

G.

(B) For any Group 2 wastewater stream or organic stream whose benzene emissions are subject to control through the use of one or more treatment processes or waste management units under the provisions of 40 C FR part 61, subpart FF on or after December 31, 1992, comply with the requirements of §63.133 through §63.147 of subpart G for Group 1 wastewater streams.

(p) Overlap of subpart CC with other regulations for equipment leaks.

(1) After the compliance dates specified in paragraph (h) of this section, equipment leaks that are also subject to the provisions of 40 CFR parts 60 and 61 standards promulgated before September 4, 2007, are required to comply only with the provisions specified in this subpart.

(2) Equ ipment leaks that are also subject to the provisions of 40 CFR part 60, subpart GGGa, are required to comply only with the provisions specified in 40 CFR part 60, subpart GGGa.

(q) For overlap of subpart CC with local or State regulations, the permitting a uthority for the affected source may allow consolidation of the monitoring, recordkeeping, and reporting requirements under this subpart with the monitoring, recordkeeping, and reporting requirements under other applicable requirements in 40 CFR parts 60, 61, or 63, and in any 40 CFR part 52 approved State implementation plan provided the implementation plan allows for approval of alternative monitoring, reporting, or recordkeeping requirements and provided that the permit contains an equivalent degree of c ompliance and control.

(r) Overlap of subpart CC with other regulations for gasoline loading racks. After the compliance dates specified in paragraph (h) of this section, a Group 1 gasoline loading rack that is part of a source subject to subpart CC and al so is subject to the provisions of 40 CFR part 60, subpart XX is required to comply only with this subpart.

§ 63.641 Definitions.

All terms used in this subpart shall have the meaning given them in the Clean Air Act, subpart A of this part, and in this s ection. If the same term is defined in subpart A and in this section, it shall have the meaning given in this section for purposes of this subpart.

Affected source means the collection of emission points to which this subpart applies as determined by the c riteria in §63.640.

Aliphatic means open

- chained structure consisting of paraffin, olefin and acetylene hydrocarbons

and derivatives.

Annual average true vapor pressure means the equilibrium partial pressure exerted by the stored liquid at the temperature equal to the annual average of the liquid storage temperature for liquids stored above or below the ambient temperature or at the local annual average temperaturePage 13 of 107

reported by the National Weather Service for liquids stored at the ambient temperature, as

de termined:

(1) In accordance with methods specified in §63.111 of subpart G of this part;

(2) From standard reference texts; or

(3) By any other method approved by the Administrator

.

Boiler means any enclosed combustion device that extracts useful energy in the form of steam

and is not an incinerator.

By compound means by individual stream components, not by carbon equivalents.

Car

- seal means a seal that is placed on a device that is used to change the position of a valve (e.g., from opened to closed) in suc h a way that the position of the valve cannot be changed without breaking the seal.

Closed vent system means a system that is not open to the atmosphere and is configured of piping, ductwork, connections, and, if necessary, flow inducing devices that trans port gas or

vapor from an emission point to a control device or back into the process. If gas or vapor from regulated equipment is routed to a process (e.g., to a petroleum refinery fuel gas system), the process shall not be considered a closed vent system and is not subject to closed vent system

standards.

Combustion device means an individual unit of equipment such as a flare, incinerator, process heater, or boiler used for the combustion of organic hazardous air pollutant vapors.

Connector means flanged, screwed , or other joined fittings used to connect two pipe lines or a pipe line and a piece of equipment. A common connector is a flange. Joined fittings welded completely around the circumference of the interface are not considered connectors for the

pur pose of this regulation. For the purpose of reporting and recordkeeping, connector means joined fittings that are accessible.

Continuous record means documentation , either in hard copy or computer readable form, of data values measured at least once every hour and recorded at the frequency specified in §63.655(i).

Continuous recorder means a data recording device recording an instantaneous data value or an average data value at least once every hour.

Control device means any equipment used for recovering, r emoving, or oxidizing organic hazardous air pollutants. Such equipment includes, but is not limited to, absorbers , carbon adsorbers, condensers, incinerators, flares, boilers, and process heaters. For miscellaneous process vents (as defined in this section ), recovery devices (as defined in this section) are not

considered control devices.Page 14 of 107

Cooling tower means a heat removal device used to remove the heat absorbed in circulating cooling water systems by transferring the heat to the atmosphere using natural or mechanical

draft.

Cooling tower return line means the main water trunk lines at the inlet to the cooling tower

before exposure to the atmosphere.

Delayed coker vent means a vent that is typically intermittent in nature, and usually occurs only during the initiation of the depressuring cycle of the decoking operation when vapor from the coke drums cannot be sent to the fractionator column for product recovery, but instead is routed to the atmosphere through a closed blowdown system or directly to the atmosp here in an open blowdown system. The emissions from the decoking phases of delayed coker operations, which include coke drum deheading, draining, or decoking (coke cutting), are not considered to be delayed coker vents.

Distillate receiver means overhead r eceivers, overhead accumulators, reflux drums, and condenser(s) including ejector

- condenser(s) associated with a distillation unit.

Distillation unit means a device or vessel in which one or more feed streams are separated into two or more exit streams, ea ch exit stream having component concentrations different from those in the feed stream(s). The separation is achieved by the redistribution of the components between the liquid and the vapor phases by vaporization and condensation as they approach equilibr ium within the distillation unit. Distillation unit includes the distillate receiver, reboiler, and any associated vacuum pump or steam jet.

Emission point means an individual miscellaneous process vent, storage vessel, wastewater stream, or equipment leak associated with a petroleum refining process unit; an individual storage vessel or equipment leak associated with a bulk gasoline terminal or pipeline breakout station classified under Standard Industrial Classification code 2911; a gasoline loading rack classified under Standard Industrial Classification code 2911; or a marine tank vessel loading operation located at a petroleum refinery.

Equipment leak means emissions of organic hazardous air pollutants from a pump, compressor, pressure relief device, sa mpling connection system, open

- ended valve or line, valve, or instrumentation system “in organic hazardous air pollutant service” as defined in this section. Vents from wastewater collection and conveyance systems (including, but not limited to

wastewater drains, sewer vents, and sump drains), tank mixers, and sample valves on storage tanks are not equipment leaks.

Flame zone means the portion of a combustion chamber of a boiler or process heater occupied by the flame envelope created by the primary fuel.

F lexible operation unit means a process unit that manufactures different products periodically by alternating raw materials or operating conditions. These units are also referred to as campaign plants or blocked operations.Page 15 of 107

Flow indicator means a device tha t indicates whether gas is flowing, or whether the valve position would allow gas to flow, in a line.

Fuel gas system means the offsite and onsite piping and control system that gathers gaseous

streams generated by refinery operations, may blend them with sources of gas, if available, and transports the blended gaseous fuel at suitable pressures for use as fuel in heaters, furnaces, boilers, incinerators, gas turbines, and other combustion devices located within or outside of the refinery. The fuel is piped directly to each individual combustion device, and the system typically operates at pressures over atmospheric. The gaseous streams can contain a mixture of methane, light hydrocarbons, hydrogen and other miscellaneous species.

Gasoline means any petroleu m distillate or petroleum distillate/alcohol blend having a Reid vapor pressure of 27.6 kilopascals or greater that is used as a fuel for internal combustion engines.

Gasoline loading rack means the loading arms, pumps, meters, shutoff valves, relief valve s, and other piping and valves necessary to fill gasoline cargo tanks.

Group 1 gasoline loading rack means any gasoline loading rack classified under Standard

Industrial Classification code 2911 that is located within a bulk gasoline terminal that has a

ga soline throughput greater than 75,700 liters per day. Gasoline throughput shall be the maximum calculated design throughput for the terminal as may be limited by compliance with enforceable conditions under Federal, State, or local law and discovered by th e Administrator and any other person.

Group 1 marine tank vessel means a vessel at an existing source loaded at any land

- or sea

- based terminal or structure that loads liquid commodities with vapor pressures greater than or equal to 10.3 kilopascals in bul k onto marine tank vessels, that emits greater than 9.1 megagrams of any individual HAP or 22.7 megagrams of any combination of HAP annually after August 18, 1999, or a vessel at a new source loaded at any land

- or sea

- based terminal or structure that load s liquid commodities with vapor pressures greater than or equal to 10.3 kilopascals onto marine tank

vessels.

Group 1 miscellaneous process vent means a miscellaneous process vent for which the total organic HAP concentration is greater than or equal to 20 parts per million by volume, and the total volatile organic compound emissions are greater than or equal to 33 kilograms per day for existing sources and 6.8 kilograms per day for new sources at the outlet of the final recovery device (if any) and prior t o any control device and prior to discharge to the atmosphere.

Group 1 storage vessel means a storage vessel at an existing source that has a design capacity greater than or equal to 177 cubic meters and stored

- liquid maximum true vapor pressure greater

th an or equal to 10.4 kilopascals and stored

- liquid annual average true vapor pressure greater than or equal to 8.3 kilopascals and annual average HAP liquid concentration greater than 4 percent by weight total organic HAP; a storage vessel at a new source t hat has a design storage capacity greater than or equal to 151 cubic meters and stored

- liquid maximum true vapor pressure greater than or equal to 3.4 kilopascals and annual average HAP liquid concentrationPage 16 of 107

greater than 2 percent by weight total organic HA P; or a storage vessel at a new source that has a design storage capacity greater than or equal to 76 cubic meters and less than 151 cubic meters

and stored

- liquid maximum true vapor pressure greater than or equal to 77 kilopascals and annual average HAP l iquid concentration greater than 2 percent by weight total organic HAP.

Group 1 wastewater stream means a wastewater stream at a petroleum refinery with a total annual benzene loading of 10 megagrams per year or greater as calculated according to the

proce dures in 40 CFR 61.342 of subpart FF of part 61 that has a flow rate of 0.02 liters per minute or greater, a benzene concentration of 10 parts per million by weight or greater, and is not exempt from control requirements under the provisions of 40 CFR part 61, subpart FF.

Group 2 gasoline loading rack means a gasoline loading rack classified under Standard Industrial Classification code 2911 that does not meet the definition of a Group 1 gasoline loading rack.

Group 2 marine tank vessel means a marine tank vessel that does not meet the definition of a Group 1 marine tank vessel.

Group 2 miscellaneous process vent means a miscellaneous process vent that does not meet the definition of a Group 1 miscellaneous process vent.

Group 2 storage vessel means a storag e vessel that does not meet the definition of a Group 1 storage vessel.

Group 2 wastewater stream means a wastewater stream that does not meet the definition of Group 1 wastewater stream.

Hazardous air pollutant or HAP means one of the chemicals listed in section 112(b) of the Clean

Air Act.

Heat exchange system means a device or collection series of devices used to transfer heat from process fluids to water without intentional direct contact of the process fluid with the water ( i.e.,

non

- contact heat exchan ger) and to transport and/or cool the water in a closed

- loop recirculation system (cooling tower system) or a once

- through system ( e.g., river or pond water). For closed

loop recirculation systems, the heat exchange system consists of a cooling tower, all heat exchangers that are serviced by that cooling tower

, and all water lines to and from the heat exchanger(s). For once

- through systems, the heat exchange system consists of one or more heat exchangers servicing an individual process unit and all water li nes to and from the heat exchanger(s). Intentional direct contact with process fluids results in the formation of a

wastewater.

Heat exchanger exit line means the cooling water line from the exit of one or more heat exchangers (where cooling water leaves t he heat exchangers) to either the entrance of the cooling tower return line or prior to exposure to the atmosphere, in, as an example, a once

- through cooling system, whichever occurs first.Page 17 of 107

Incinerator means an enclosed combustion device that is used for d estroying organic compounds. Auxiliary fuel may be used to heat waste gas to combustion temperatures. Any energy recovery section present is not physically formed into one manufactured or assembled unit with the combustion section; rather, the energy recov ery section is a separate section following the combustion section and the two are joined by ducts or connections carrying flue

gas.

In heavy liquid service means that the piece of equipment is not in gas/vapor service or in light liquid service.

In light liquid service means that the piece of equipment contains a liquid that meets the

conditions specified in §60.593(d) of part 60, subpart GGG.

In organic hazardous air pollutant service means that a piece of equipment either contains or contacts a fluid (li quid or gas) that is at least 5 percent by weight of total organic HAP ’ s as determined according to the provisions of §63.180(d) of subpart H of this part and table 1 of this subpart. The provisions of §63.180(d) of subpart H also specify how to determine that a piece of equipment is not in organic HAP service.

Leakless valve means a valve that has no external actuating mechanism.

Maximum true vapor pressure means the equilibrium partial pressure exerted by the stored liquid at the temperature equal to the highest calendar

- month average of the liquid storage temperature for liquids stored above or below the ambient temperature or at the local maximum monthly average temperature as reported by the National Weather Service for liquids stored at the

ambient tem perature, as determined:

(1) In accordance with methods specified in §63.111 of subpart G of this part ;

(2) From standard reference texts; or

(3) By any other method approved by the Administrator

.

Miscellaneous process vent means a gas stream containing gr eater than 20 parts per million by volume organic HAP that is continuously or periodically discharged during normal operation of a petroleum refining process unit meeting the criteria specified in §63.640(a). Miscellaneous process vents include gas streams that are discharged directly to the atmosphere, gas streams that are routed to a control device prior to discharge to the atmosphere, or gas streams that are diverted through a product recovery device prior to control or discharge to the atmosphere.

Misce llaneous process vents include vent streams from: caustic wash accumulators, distillation tower condensers/accumulators, flash/knockout drums, reactor vessels, scrubber overheads, stripper overheads, vacuum (steam) ejectors, wash tower overheads, water was h accumulators, blowdown condensers/accumulators, and delayed coker vents. Miscellaneous process vents do

not include:

(1) Gaseous streams routed to a fuel gas system;Page 18 of 107

(2) Relief valve discharges;

(3) Leaks from equipment regulated under §63.648;

(4) Episo dic or nonroutine releases such as those associated with startup, shutdown, malfunction, maintenance, depressuring, and catalyst transfer operations;

(5) In situ sampling systems (onstream analyzers );

(6) Catalytic cracking unit catalyst regeneration vents ;

(7) Catalytic reformer regeneration vents;

(8) Sulfur plant vents;

(9) Vents from control devices such as scrubbers, boilers, incinerators, and electrostatic precipitators applied to catalytic cracking unit catalyst regeneration vents, catalytic reformer regeneration vents, and sulfur plant vents;

(10) Vents from any stripping operations applied to comply with the wastewater provisions of this subpart, subpart G of this part, or 40 CFR part 61, subpart FF;

(11) Coking unit vents associated with coke drum depressuring at or below a coke drum outlet pressure of 15 pounds per square inch gauge, deheading, draining, or decoking (coke cutting) or pressure testing after decoking;

(12) Vents from storage vessels;

(13) Emissions from wastewater collection and conv eyance systems including, but not limited to, wastewater drains, sewer vents, and sump drains; and

(14) Hydrogen production plant vents through which carbon dioxide is removed from process streams or through which steam condensate produced or treated withi n the hydrogen plant is degassed or deaerated.

Operating permit means a permit required by 40 CFR parts 70 or 71.

Organic hazardous air pollutant or organic HAP in this subpart, means any of the organic chemicals listed in table 1 of this subpart.

Petroleu m

- based solvents means mixtures of aliphatic hydrocarbons or mixtures of one and two ring aromatic hydrocarbons.

Periodically discharged means discharges that are intermittent and associated with routine operations. Discharges associated with maintenance a ctivities or process upsets are notPage 19 of 107

considered periodically discharged miscellaneous process vents and are therefore not regulated by the petroleum refinery miscellaneous process vent provisions.

Petroleum refining process unit means a process unit used in an establishment primarily engaged in petroleum refining as defined in the Standard Industrial Classification code for petroleum refining (2911), and used primarily for the following:

(1) Producing transportation fuels (such as gasoline, diesel fuels, and jet fuels), heating fuels (such as kerosene, fuel gas distillate, and fuel oils), or lubricants;

(2) Separating petroleum; or

(3) Separating, cracking, reacting, or reforming intermediate petroleum streams.

(4) Examples of such units include, but are not limited to, petroleum

- based solvent units, alkylation units, catalytic hydrotreating, catalytic hydrorefining, catalytic hydrocracking, catalytic reforming, catalytic cracking, crude distillation, lube oil processing, hydrogen production, isomerization, po lymerization, thermal processes, and blending, sweetening, and treating processes. Petroleum refining process units also include sulfur plants.

Plant site means all contiguous or adjoining property that is under common control including properties that are separated only by a road or other public right

- of

- way. Common control includes properties that are owned, leased, or operated by the same entity, parent entity, subsidiary, or any combination thereof.

Primary fuel means the fuel that provides the principa l heat input (i.e., more than 50 percent) to the device. To be considered primary, the fuel must be able to sustain operation without the

addition of other fuels.

Process heater means an enclosed combustion device that primarily transfers heat liberated by burning fuel directly to process streams or to heat transfer liquids other than water.

Process unit means the equipment assembled and connected by pipes or ducts to process raw and/or intermediate materials and to manufacture an intended product. A proces s unit includes any associated storage vessels. For the purpose of this subpart, process unit includes, but is not limited to, chemical manufacturing process units and petroleum refining process units.

Process unit shutdown means a work practice or operati onal procedure that stops production from a process unit or part of a process unit during which it is technically feasible to clear process material from a process unit or part of a process unit consistent with safety constraints and during which repairs c an be accomplished. An unscheduled work practice or operational procedure that stops production from a process unit or part of a process unit for less than 24 hours is not considered a process unit shutdown. An unscheduled work practice or operational

proc edure that would stop production from a process unit or part of a process unit for a shorter period of time than would be required to clear the process unit or part of the process unit of materials and start up the unit, or would result in greater emission s than delay of repair of leakingPage 20 of 107

components until the next scheduled process unit shutdown is not considered a process unit shutdown. The use of spare equipment and technically feasible bypassing of equipment without stopping production are not considered process unit shutdowns.

Recovery device means an individual unit of equipment capable of and used for the purpose of recovering chemicals for use, reuse, or sale. Recovery devices include, but are not limited to, absorbers, carbon adsorbers, and condenser s.

Reference control technology for gasoline loading racks means a vapor collection and processing system used to reduce emissions due to the loading of gasoline cargo tanks to 10 milligrams of total organic compounds per liter of gasoline loaded or less.

Reference control technology for marine vessels means a vapor collection system and a control device that reduces captured HAP emissions by 97 percent

.

Reference control technology for miscellaneous process vents means a combustion device used

to reduce or ganic HAP emissions by 98 percent, or to an outlet concentration of 20 parts per million by volume.

Reference control technology for storage vessels means either:

(1) An internal floating roof meeting the specifications of §63.119(b) of subpart G except fo r §63.119 (b)(5) and (b)(6);

(2) An external floating roof meeting the specifications of §63.119(c) of subpart G except for §63.119(c)(2);

(3) An external floating roof converted to an internal floating roof meeting the specifications of §63.119(d) of subp art G except for §63.119(d)(2); or

(4) A closed

- vent system to a control device that reduces organic HAP emissions by 95

- percent,

or to an outlet concentration of 20 parts per million by volume.

(5) For purposes of emissions averaging, these four technolog ies are considered equivalent.

Reference control technology for wastewater means the use of:

(1) Controls specified in §§61.343 through 61.347 of subpart FF of part 61;

(2) A treatment process that achieves the emission reductions specified in table 7 of t his subpart for each individual HAP present in the wastewater stream or is a steam stripper that meets the specifications in §63.138(g) of subpart G of this part; and

(3) A control device to reduce by 95 percent (or to an outlet concentration of 20 parts p er million by volume for combustion devices) the organic HAP emissions in the vapor streams vented fromPage 21 of 107

treatment processes (including the steam stripper described in paragraph (2) of this definition) managing wastewater.

Refinery fuel gas means a gaseous mixture of methane, light hydrocarbons, hydrogen, and other miscellaneous species (nitrogen, carbon dioxide, hydrogen sulfide, etc.) that is produced in the refining of crude oil and/or petrochemical processes and that is separated for use as a fuel in

boi lers and process heaters throughout the refinery.

Relief valve means a valve used only to release an unplanned, nonroutine discharge. A relief valve discharge can result from an operator error, a malfunction such as a power failure or equipment failure, or other unexpected cause that requires immediate venting of gas from process equipment in order to avoid safety hazards or equipment damage.

Research and development facility means laboratory and pilot plant operations whose primary purpose is to conduct re search and development into new processes and products, where the operations are under the close supervision of technically trained personnel, and is not engaged in the manufacture of products for commercial sale, except in a de minimis manner.

Shutdown me ans the cessation of a petroleum refining process unit or a unit operation (including, but not limited to, a distillation unit or reactor) within a petroleum refining process unit for purposes including, but not limited to, periodic maintenance, replacemen t of equipment, or repair.

Startup means the setting into operation of a petroleum refining process unit for purposes of production. Startup does not include operation solely for purposes of testing equipment. Startup does not include changes in product fo r flexible operation units.

Storage vessel means a tank or other vessel that is used to store organic liquids. Storage vessel

does not include:

(1) Vessels permanently attached to motor vehicles such as trucks, railcars, barges, or ships;

(2) Pressure vess els designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere;

(3) Vessels with capacities smaller than 40 cubic meters;

(4) Bottoms receiver tanks; or

(5) Wastewater storage tanks. Wastewater storage tanks are covered unde r the wastewater provisions.

Temperature monitoring device means a unit of equipment used to monitor temperature and having an accuracy of ±1 percent of the temperature being monitored expressed in degrees Celsius or ±0.5 °C, whichever is greater.Page 22 of 107

Total an nual benzene means the total amount of benzene in waste streams at a facility on an annual basis as determined in §61.342 of 40 CFR part 61, subpart FF.

Total organic compounds or TOC, as used in this subpart, means those compounds excluding

methane and et hane measured according to the procedures of Method 18 of 40 CFR part 60, appendix A. Method 25A may be used alone or in combination with Method 18 to measure TOC as provided in §63.645 of this subpart.

Wastewater means water or wastewater that, during pro duction or processing, comes into direct contact with or results from the production or use of any raw material, intermediate product, finished product, byproduct, or waste product and is discharged into any individual drain system. Examples are feed tank drawdown; water formed during a chemical reaction or used as a reactant; water used to wash impurities from organic products or reactants; water used to cool or quench organic vapor streams through direct contact; and condensed steam from jet ejector

syste ms pulling vacuum on vessels containing organics.

§ 63.642 General standards.

(a) Each owner or operator of a source subject to this subpart is required to apply for a part 70 or part 71 operating permit from the appropriate permitting authority. If the EPA has approved a State operating permit program under part 70, the permit shall be obtained from the State authority. If the State operating permit program has not been approved, the source shall apply to the EPA Regional Office pursuant to part 71.

(b) [Reserved]

(c) Table 6 of this subpart specifies the provisions of subpart A of this part that apply and those that do not apply to owners and operators of sources subject to this subpart.

(d) Initial performance tests and initial compliance determinations shall be required only as specified in this subpart.

(1) Performance tests and compliance determinations shall be conducted according to the schedule and procedures specified in this subpart.

(2) The owner or operator shall notify the Administrator of the intention to conduct a performance test at least 30 days before the performance test is scheduled.

(3) Performance tests shall be conducted according to the provisions of §63.7(e) except that performance tests shall be conducted at maximum representative operating capacity for the process. During the performance test, an owner or operator shall operate the control device at either maximum or minimum representative operating conditions for monitored control device parameters, whichever results in lower emis sion reduction.Page 23 of 107

(4) Data shall be reduced in accordance with the EPA

- approved methods specified in the applicable section or, if other test methods are used, the data and methods shall be validated according to the protocol in Method 301 of appendix A of t his part.

(e) Each owner or operator of a source subject to this subpart shall keep copies of all applicable reports and records required by this subpart for at least 5 years except as otherwise specified in this subpart. All applicable records shall be ma intained 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, floppy disk, magnetic tape, or

microfiche.

(f) All r eports required under this subpart shall be sent to the Administrator at the addresses listed in §63.13 of subpart A of this part. If acceptable to both the Administrator and the owner or operator of a source, reports may be submitted on electronic media.

(g) The owner or operator of an existing source subject to the requirements of this subpart shall control emissions of organic HAP ’ s to the level represented by the following equation:

E A = 0.02Σ EPV 1 + Σ EPV 2 + 0.05Σ ES 1 + Σ ES 2 + Σ EGLR 1C + Σ EGLR 2 + (R) Σ EMV 1 + Σ

EMV 2 + Σ EWW 1C + Σ EWW 2

where:

E A = Emission rate, megagrams per year, allowed for the source.

0.02Σ EPV 1 = Sum of the residual emissions, megagrams per year, from all Group 1 miscellaneous process vents, as defined in §63.641.

Σ EPV 2 = Sum of the emissions, megagrams per year, from all Group 2 process vents, as defined in §63.641.

0.05Σ ES 1 = Sum of the residual emissions, megagrams per year, from all Group 1 storage vessels, as defined in §63.641.

Σ ES 2 = Sum of the emissions, megagrams per ye ar, from all Group 2 storage vessels, as defined in §63.641.

Σ EGLR 1C = Sum of the residual emissions, megagrams per year, from all Group 1 gasoline loading racks, as defined in §63.641.

Σ EGLR 2 = Sum of the emissions, megagrams per year, from all Group 2 gasoline loading racks, as defined in §63.641.

(R)Σ EMV 1 = Sum of the residual emissions megagrams per year, from all Group 1 marine tank vessels, as defined in §63.641.Page 24 of 107

R = 0.03 for existing sources, 0.02 for new sources.

Σ EMV 2 = Sum of the emissions, me gagrams per year from all Group 2 marine tank vessels, as defined in §63.641.

Σ EWW 1C = Sum of the residual emissions from all Group 1 wastewater streams, as defined in §63.641. This term is calculated for each Group 1 stream according to the equation for EWW ic in §63.652(h)(6).

Σ EWW 2 = Sum of emissions from all Group 2 wastewater streams, as defined in §63.641.

The emissions level represented by this equation is dependent on the collection of emission points in the source. The level is not fixed and can c hange as the emissions from each emission point change or as the number of emission points in the source changes.

(h) The owner or operator of a new source subject to the requirements of this subpart shall control emissions of organic HAP ’ s to the level re presented by the equation in paragraph (g) of

this section.

(i) The owner or operator of an existing source shall demonstrate compliance with the emission standard in paragraph (g) of this section by following the procedures specified in paragraph (k)

of t his section for all emission points, or by following the emissions averaging compliance approach specified in paragraph (l) of this section for specified emission points and the procedures specified in paragraph (k) of this section for all other emission p oints within the

source.

(j) The owner or operator of a new source shall demonstrate compliance with the emission standard in paragraph (h) of this section only by following the procedures in paragraph (k) of this section. The owner or operator of a new so urce may not use the emissions averaging compliance approach.

(k) The owner or operator of an existing source may comply, and the owner or operator of a new source shall comply, with the miscellaneous process vent provisions in §§63.643 through 63.645,

the storage vessel provisions in §63.646, the wastewater provisions in §63.647, the gasoline loading rack provisions in §63.650, and the marine tank vessel loading operation provisions in §63.651 of this subpart.

(1) The owner or operator using this complianc e approach shall also comply with the requirements of §63.655 as applicable.

(2) The owner or operator using this compliance approach is not required to calculate the annual emission rate specified in paragraph (g) of this section.

(l) The owner or operato r of an existing source may elect to control some of the emission points within the source to different levels than specified under §§63.643 through 63.647, §§63.650 and 63.651 by using an emissions averaging compliance approach as long as the overall emis sionsPage 25 of 107

for the source do not exceed the emission level specified in paragraph (g) of this section. The owner or operator using emissions averaging shall meet the requirements in paragraphs (l)(1) and (l)(2) of this section.

(1) Calculate emission debits and credits for those emission points involved in the emissions average according to the procedures specified in §63.652; and

(2) Comply with the requirements of §§63.652, 63.653, and 63.655, as applicable.

(m) A State may restrict the owner or operator of an existing source to using only the procedures in paragraph (k) of this section to comply with the emission standard in paragraph (g) of this section. Such a restriction would preclude the source from using an emissions averaging compliance approach.

§ 63.6 43 Miscellaneous process vent provisions.

(a) The owner or operator of a Group 1 miscellaneous process vent as defined in §63.641 shall comply with the requirements of either paragraphs (a)(1) or (a)(2) of this section.

(1) Reduce emissions of organic HA P ’ s using a flare that meets the requirements of §63.11(b) of subpart A of this part.

(2) Reduce emissions of organic HAP ’ s, using a control device, by 98 weight

- percent or to a concentration of 20 parts per million by volume, on a dry basis, corrected to 3 percent oxygen, whichever is less stringent. Compliance can be determined by measuring either organic HAP ’ s or TOC ’ s using the procedures in §63.645.

(b) If a boiler or process heater is used to comply with the percentage of reduction requirement

or conc entration limit specified in paragraph (a)(2) of this section, then the vent stream shall be introduced into the flame zone of such a device, or in a location such that the required percent reduction or concentration is achieved. Testing and monitoring is required only as specified in §63.644(a) and §63.645 of this subpart.

§ 63.644 Monitoring provisions for miscellaneous process vents.

(a) Except as provided in paragraph (b) of this section, each owner or operator of a Group 1 miscellaneous process vent that uses a combustion device to comply with the requirements in §63.643(a) shall install the monitoring equipment specified in paragraph (a)(1), (a)(2), (a)(3), or (a)(4) of this section, depending on the type of combustion device used. All monitoring

equ ipment 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.

(1) Where an incinerator is used, a temperatu re monitoring device equipped with a continuous recorder is required.Page 26 of 107

(i) Where an incinerator other than a catalytic incinerator is used, a temperature monitoring device shall be installed in the firebox or in the ductwork immediately downstream of the fi rebox in a position before any substantial heat exchange occurs.

(ii) Where a catalytic incinerator is used, temperature monitoring devices shall be installed in the gas stream immediately before and after the catalyst bed.

(2) Where a flare is used, a dev ice (including but not limited to a thermocouple, an ultraviolet beam sensor, or an infrared sensor) capable of continuously detecting the presence of a pilot flame is required.

(3) Any boiler or process heater with a design heat input capacity greater tha n or equal to 44 megawatt or any boiler or process heater in which all vent streams are introduced into the flame zone is exempt from monitoring.

(4) Any boiler or process heater less than 44 megawatts design heat capacity where the vent

stream is not intr oduced into the flame zone is required to use a temperature monitoring device in the firebox equipped with a continuous recorder.

(b) An owner or operator of a Group 1 miscellaneous process vent may request approval to monitor parameters other than those l isted in paragraph (a) of this section. The request shall be submitted according to the procedures specified in §63.655(h). Approval shall be requested if the

owner or operator:

(1) Uses a control device other than an incinerator, boiler, process heater, o r flare; or

(2) Uses one of the control devices listed in paragraph (a) of this section, but seeks to monitor a parameter other than those specified in paragraph (a) of this section.

(c) The owner or operator of a Group 1 miscellaneous process vent using a vent system that contains bypass lines that could divert a vent stream away from the control device used to comply with paragraph (a) of this section shall comply with either paragraph (c)(1) or (c)(2) of this section. Equipment such as low leg drains, hi gh point bleeds, analyzer vents, open

- ended valves or lines, pressure relief valves needed for safety reasons, and equipment subject to §63.648 are not subject to this paragraph.

(1) Install, calibrate, maintain, and operate a flow indicator that determine s whether a vent stream flow is present at least once every hour. Records shall be generated as specified in §63.655(h) and (i). The flow indicator shall be installed at the entrance to any bypass line that could divert the vent stream away from the contro l device to the atmosphere; or

(2) Secure the bypass line valve in the closed position with a car

- seal or a lock

- and

- key type configuration. A visual inspection of the seal or closure mechanism shall be performed at least once every month to ensure that th e valve is maintained in the closed position and the vent stream is not diverted through the bypass line.Page 27 of 107

(d) The owner or operator shall establish a range that ensures compliance with the emissions standard for each parameter monitored under paragraphs (a ) and (b) of this section. In order to establish the range, the information required in §63.655(f)(3) shall be submitted in the Notification of Compliance Status report.

(e) Each owner or operator of a control device subject to the monitoring provisions of this section shall operate the control device in a manner consistent with the minimum and/or maximum operating parameter value or procedure required to be monitored under paragraphs (a) and (b) of this section. 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 by this section shall constitute a violation of the applicable emission standard of this subpart.

§ 63.645 Test methods and procedures f or miscellaneous process vents.

(a) To demonstrate compliance with §63.643, an owner or operator shall follow §63.116 except for §63.116 (a)(1), (d) and (e) of subpart G of this part except as provided in paragraphs (b) through (d) and paragraph (i) of thi s section.

(b) All references to §63.113(a)(1) or (a)(2) in §63.116 of subpart G of this part shall be replaced with §63.643(a)(1) or (a)(2), respectively.

(c) In §63.116(c)(4)(ii)(C) of subpart G of this part, organic HAP ’ s in the list of HAP ’ s in table 1 of this subpart shall be considered instead of the organic HAP ’ s in table 2 of subpart F of this

part.

(d) All references to §63.116(b)(1) or (b)(2) shall be replaced with paragraphs (d)(1) and (d)(2) of this section, respectively.

(1) Any boiler or proce ss heater with a design heat input capacity of 44 megawatts or greater.

(2) Any boiler or process heater in which all vent streams are introduced into the flame zone.

(e) For purposes of determining the TOC emission rate, as specified under paragraph (f) o f this section, the sampling site shall be after the last product recovery device (as defined in §63.641 of this subpart) (if any recovery devices are present) but prior to the inlet of any control device (as defined in §63.641 of this subpart) that is pre sent, prior to any dilution of the process vent stream, and prior to release to the atmosphere.

(1) Methods 1 or 1A of 40 CFR part 60, appendix A, as appropriate, shall be used for selection of the sampling site.

(2) No traverse site selection method is ne eded for vents smaller than 0.10 meter in diameter.

(f) Except as provided in paragraph (g) of this section, an owner or operator seeking to demonstrate that a process vent TOC mass flow rate is less than 33 kilograms per day for an existing source or less than 6.8 kilograms per day for a new source in accordance with the GroupPage 28 of 107

2 process vent definition of this subpart shall determine the TOC mass flow rate by the following procedures:

(1) The sampling site shall be selected as specified in paragraph (e) of this section.

(2) The gas volumetric flow rate shall be determined using Methods 2, 2A, 2C, or 2D of 40 CFR part 60, appendix A, as appropriate.

(3) Method 18 or Method 25A of 40 CFR part 60, appendix A shall be used to measure concentration; alternativel y, any other method or data that has been validated according to the protocol in Method 301 of appendix A of this part may be used. If Method 25A is used, and the TOC mass flow rate calculated from the Method 25A measurement is greater than or equal to 33 kilograms per day for an existing source or 6.8 kilograms per day for a new source, Method 18 may be used to determine any non

- VOC hydrocarbons that may be deducted to calculate the TOC (minus non

- VOC hydrocarbons) concentration and mass flow rate. The fol lowing procedures shall be used to calculate parts per million by volume concentration:

(i) The minimum sampling time for each run shall be 1 hour in which either an integrated sample or four grab samples shall be taken. If grab sampling is used, then the samples shall be taken at approximately equal intervals in time, such as 15

- minute intervals during the run.

(ii) The TOC concentration (C TOC ) is the sum of the concentrations of the individual components and shall be computed for each run using the follow ing equation if Method 18 is used:

where:

C TOC = Concentration of TOC (minus methane and ethane), dry basis, parts per million by

volume.

C

ji = Concentration of s ample component j of the sample i, dry basis, parts per million by

volume.

n = Number of components in the sample.

x = Number of samples in the sample run.

(4) The emission rate of TOC (minus methane and ethane) (E TOC ) shall be calculated using the

followi ng equation if Method 18 is used:Page 29 of 107

where:

E = Emission rate of TOC (minus methane and ethane) in the sample, kilograms per day.

K 2 = Constant , 5.986 × 10 −5 ( parts per million) −1 ( gram

- mole per standard cubic meter) (kilogram per gram) (minute per day), where the standard temperature (standard cubic meter) is

at 20 °C.

C

j = Concentration on a dry basis of organic compound j in parts per million as measured by

Method 18 of 40 CFR part 60, appendix A, as indicated in paragraph (f)(3) of this section. C j includes all organic compounds measured minus methane and ethane.

M

j = Molecular weight of organic compound j, gram per gram

- mole.

Q

s = Vent stream flow rate, dry standa rd cubic meters per minute, at a temperature of 20 °C.

(5) If Method 25A is used, the emission rate of TOC (E TOC ) shall be calculated using the following equation:

E TOC = K 2 C TOC MQ

s

where:

E TOC =Emission rate of TOC (minus methane and ethane) in the sample, kilograms per day.

K 2 = Constant , 5.986×10

– 5 (parts per million) −1 (gram

- mole per standard cubic meter) (kilogram per gram)(minute per day), where the standard temperature (standard cubic meter) is at 20 °C.

C TOC = Concentration of TOC on a dry basis in pa rts per million volume as measured by Method 25A of 40 CFR part 60, appendix A, as indicated in paragraph (f)(3) of this section.

M = Molecular weight of organic compound used to express units of C TOC , gram per gram

- mole.

Q

s = Vent stream flow rate, dry st andard cubic meters per minute, at a temperature of 20 °C.

(g) Engineering assessment may be used to determine the TOC emission rate for the representative operating condition expected to yield the highest daily emission rate.

(1) Engineering assessment in cludes, but is not limited to, the following:

(i) Previous test results provided the tests are representative of current operating practices at the process unit.Page 30 of 107

(ii) Bench

- scale or pilot

- scale test data representative of the process under representative

o perating conditions.

(iii) TOC emission rate specified or implied within a permit limit applicable to the process vent.

(iv) Design analysis based on accepted chemical engineering principles, measurable process

parameters, or physical or chemical laws or p roperties. Examples of analytical methods include,

but are not limited to:

(A) Use of material balances based on process stoichiometry to estimate maximum TOC concentrations;

(B) Estimation of maximum flow rate based on physical equipment design such as pu mp or blower capacities; and

(C) Estimation of TOC concentrations based on saturation conditions.

(v) All data, assumptions, and procedures used in the engineering assessment shall be

documented.

(h) The owner or operator of a Group 2 process vent shall re calculate the TOC emission rate for each process vent, as necessary, whenever process changes are made to determine whether the vent is in Group 1 or Group 2. Examples of process changes include, but are not limited to, changes in production capacity, prod uction rate, or catalyst type, or whenever there is replacement, removal, or addition of recovery equipment. For purposes of this paragraph, process changes do not include: process upsets; unintentional, temporary process changes; and changes that are with in the range on which the original calculation was based.

(1) The TOC emission rate shall be recalculated based on measurements of vent stream flow rate and TOC as specified in paragraphs (e) and (f) of this section, as applicable, or on best engineering a ssessment of the effects of the change. Engineering assessments shall meet the specifications in paragraph (g) of this section.

(2) Where the recalculated TOC emission rate is greater than 33 kilograms per day for an existing source or greater than 6.8 kil ograms per day for a new source, the owner or operator shall submit a report as specified in §63.655(f), (g), or (h) and shall comply with the appropriate provisions in §63.643 by the dates specified in §63.640.

(i) A compliance determination for visible e missions shall be conducted within 150 days of the compliance date using Method 22 of 40 CFR part 60, appendix A, to determine visible

emissions.Page 31 of 107

§ 63.646 Storage vessel provisions.

(a) Each owner or operator of a Group 1 storage vessel subject to this s ubpart shall comply with the requirements of §§63.119 through 63.121 except as provided in paragraphs (b) through (l) of

this section.

(b) As used in this section , all terms not defined in §63.641 shall have the meaning given them in 40 CFR part 63, subpar ts A or G. The Group 1 storage vessel definition presented in §63.641 shall apply in lieu of the Group 1 storage vessel definitions presented in tables 5 and 6 of §63.119 of subpart G of this part.

(1) An owner or operator may use good engineering judgment or test results to determine the stored liquid weight percent total organic HAP for purposes of group determination. Data, assumptions, and procedures used in the determination shall be documented.

(2) When an owner or operator and the Administrator do no t 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, Method 18 of 40 CFR part 60, appe ndix A shall be used.

(c) The following paragraphs do not apply to storage vessels at existing sources subject to this subpart: §63.119 (b)(5), (b)(6), (c)(2), and (d)(2).

(d) References shall apply as specified in paragraphs (d)(1) through (d)(10) of this section.

(1) All references to §63.100(k) of subpart F of this part (or the schedule provisions and the compliance date) shall be replaced with §63.640(h),

(2) All references to April 22, 1994 shall be replaced with August 18, 1995.

(3) All references to December 31, 1992 shall be replaced with July 15, 1994.

(4) All references to the compliance dates specified in §63.100 of subpart F shall be replaced with §63.640 (h) through (m).

(5) All references to §63.150 in §63.119 of subpart G of this part shall be replaced with §63.652.

(6) All references to §63.113(a)(2) of subpart G shall be replaced with §63.643(a)(2) of this subpart.

(7) All references to §63.126(b)(1) of subpart G shall be replaced with §63.422(b) of subpart R of this part.

(8) All references to §63.128(a) of subpart G shall be replaced with §63.425, paragraphs (a) through (c) and (e) through (h) of subpart R of this part.Page 32 of 107

(9) All references to §63.139(d)(1) in §63.120(d)(1)(ii) of subpart G are not applicable. For sources subject to this subpa rt, such references shall mean that 40 CFR 61.355 is applicable.

(10) All references to §63.139(c) in §63.120(d)(1)(ii) of subpart G are not applicable. For sources subject to this subpart, such references shall mean that §63.647 of this subpart is applica ble.

(e) When complying with the inspection requirements of §63.120 of subpart G of this part, owners and operators of storage vessels at existing sources subject to this subpart are not required to comply with the provisions for gaskets, slotted membranes , and sleeve seals.

(f) The following paragraphs (f)(1), (f)(2), and (f)(3) of this section apply to Group 1 storage vessels at existing sources:

(1) If a cover or lid is installed on an opening on a floating roof, the cover or lid shall remain

closed exce pt when the cover or lid must be open for access.

(2) Rim space vents are to be set to open only when the floating roof is not floating or when the pressure beneath the rim seal exceeds the manufacturer ’ s recommended setting.

(3) Automatic bleeder vents ar e to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports.

(g) Failure to perform inspections and monitoring required by this section shall constitute a violation of the appl icable standard of this subpart.

(h) References in §§63.119 through 63.121 to §63.122(g)(1), §63.151, and references to initial notification requirements do not apply.

(i) References to the Implementation Plan in §63.120, paragraphs (d)(2) and (d)(3)(i) sh all be replaced with the Notification of Compliance Status report.

(j) References to the Notification of Compliance Status report in §63.152(b) mean the Notification of Compliance Status required by §63.655(f).

(k) References to the Periodic Reports in §63 .152(c) mean the Periodic Report required by §63.655(g).

(l) The State or local permitting authority can waive the notification requirements of §§63.120(a)(5), 63.120(a)(6), 63.120(b)(10)(ii), and 63.120(b)(10)(iii) for all or some storage vessels at petro leum refineries subject to this subpart. The State or local permitting authority may also grant permission to refill storage vessels sooner than 30 days after submitting the notifications in §§63.120(a)(6) or 63.120(b)(10)(iii) for all storage vessels at a refinery or for individual storage vessels on a case

- by

- case basis.Page 33 of 107

§ 63.647 Wastewater provisions.

(a) Except as provided in paragraph (b) of this section, each owner or operator of a Group 1 wastewater stream shall comply with the requirements of §§61 .340 through 61.355 of 40 CFR part 61, subpart FF for each process wastewater stream that meets the definition in §63.641.

(b) As used in this section, all terms not defined in §63.641 shall have the meaning given them in the Clean Air Act or in 40 CFR par t 61, subpart FF, §61.341.

(c) Each owner or operator required under subpart FF of 40 CFR part 61 to perform periodic measurement of benzene concentration in wastewater, or to monitor process or control device operating parameters shall operate in a manner consistent with the minimum or maximum (as appropriate) permitted concentration or operating parameter values. Operation of the process, treatment unit, or control device resulting in a measured concentration or operating parameter value outside the permi tted limits shall constitute a violation of the emission standards. Failure to perform required leak monitoring for closed vent systems and control devices or failure to repair leaks within the time period specified in subpart FF of 40 CFR part 61 shall co nstitute a violation

of the standard.

§ 63.648 Equipment leak standards.

(a) Each owner or operator of an existing source subject to the provisions of this subpart shall comply with the provisions of 40 CFR part 60 subpart VV and paragraph (b) of this se ction except as provided in paragraphs (a)(1), (a)(2), and (c) through (i) of this section. Each owner or operator of a new source subject to the provisions of this subpart shall comply with subpart H of this part except as provided in paragraphs (c) throu gh (i) of this section.

(1) For purposes of compliance with this section, the provisions of 40 CFR part 60, subpart VV apply only to equipment in organic HAP service, as defined in §63.641 of this subpart.

(2) Calculation of percentage leaking equipment co mponents for subpart VV of 40 CFR part 60 may be done on a process unit basis or a sourcewide basis. Once the owner or operator has decided, all subsequent calculations shall be on the same basis unless a permit change is made.

(b) The use of monitoring da ta generated before August 18, 1995 to qualify for less frequent monitoring of valves and pumps as provided under 40 CFR part 60 subpart VV or subpart H of this part and paragraph (c) of this section (i.e., quarterly or semiannually) is governed by the

req uirements of paragraphs (b)(1) and (b)(2) of this section.

(1) Monitoring data must meet the test methods and procedures specified in §60.485(b) of 40 CFR part 60, subpart VV or §63.180(b)(1) through (b)(5) of subpart H of this part except for minor depart ures.

(2) Departures from the criteria specified in §60.485(b) of 40 CFR part 60 subpart VV or §63.180(b)(1) through (b)(5) of subpart H of this part or from the monitoring frequency specified in subpart VV or in paragraph (c) of this section (such as ever y 6 weeks instead of monthly orPage 34 of 107

quarterly) are minor and do not significantly affect the quality of the data. An example of a minor departure is monitoring at a slightly different frequency (such as every 6 weeks instead of monthly or quarterly). Failure t o use a calibrated instrument is not considered a minor departure.

(c) In lieu of complying with the existing source provisions of paragraph (a) in this section, an owner or operator may elect to comply with the requirements of §§63.161 through 63.169,

63. 171, 63.172, 63.175, 63.176, 63.177, 63.179, and 63.180 of subpart H of this part except as provided in paragraphs (c)(1) through (c)(10) and (e) through (i) of this section.

(1) The instrument readings that define a leak for light liquid pumps subject to §63.163 of subpart H of this part and gas/vapor and light liquid valves subject to §63.168 of subpart H of this part are specified in table 2 of this subpart.

(2) In phase III of the valve standard, the owner or operator may monitor valves for leaks as

spe cified in paragraphs (c)(2)(i) or (c)(2)(ii) of this section

.

(i) If the owner or operator does not elect to monitor connectors, then the owner or operator shall monitor valves according to the frequency specified in table 8 of this subpart.

(ii) If an own er or operator elects to monitor connectors according to the provisions of §63.649, paragraphs (b), (c), or (d), then the owner or operator shall monitor valves at the frequencies specified in table 9 of this subpart.

(3) The owner or operator shall decide no later than the first required monitoring period after the phase I compliance date specified in §63.640(h) whether to calculate the percentage leaking valves on a process unit basis or on a sourcewide basis. Once the owner or operator has decided,

all s ubsequent calculations shall be on the same basis unless a permit change is made.

(4) The owner or operator shall decide no later than the first monitoring period after the phase III compliance date specified in §63.640(h) whether to monitor connectors acc ording to the provisions in §63.649, paragraphs (b), (c), or (d).

(5) Connectors in gas/vapor service or light liquid service are subject to the requirements for connectors in heavy liquid service in §63.169 of subpart H of this part (except for the agitat or provisions). The leak definition for valves, connectors, and instrumentation systems subject to §63.169 is 1,000 parts per million.

(6) In phase III of the pump standard, except as provided in paragraph (c)(7) of this section, owners or operators that a chieve less than 10 percent of light liquid pumps leaking or three light liquid pumps leaking, whichever is greater, shall monitor light liquid pumps monthly.

(7) Owners or operators that achieve less than 3 percent of light liquid pumps leaking or one lig ht liquid pump leaking, whichever is greater, shall monitor light liquid pumps quarterly.Page 35 of 107

(8) An owner or operator may make the election described in paragraphs (c)(3) and (c)(4) of this section at any time except that any election to change after the init ial election shall be treated as a permit modification according to the terms of part 70 of this chapter.

(9) When complying with the requirements of §63.168(e)(3)(i), non

- repairable valves shall be included in the calculation of percent leaking valves the first time the valve is identified as leaking and non

- repairable. Otherwise, a number of non

- repairable valves up to a maximum of 1 percent per year of the total number of valves in organic HAP service up to a maximum of 3 percent may be excluded from cal culation of percent leaking valves for subsequent monitoring periods. When the number of non

- repairable valves exceeds 3 percent of the total number of valves in organic HAP service, the number of non

- repairable valves exceeding 3 percent of the

total numb er shall be included in the calculation of percent leaking valves.

(10) If in phase III of the valve standard any valve is designated as being leakless, the owner or operator has the option of following the provisions of 40 CFR 60.482

– 7(f). If an owner or operator chooses to comply with the provisions of 40 CFR 60.482

– 7(f), the valve is exempt from the valve monitoring provisions of §63.168 of subpart H of this part.

(d) Upon startup of new sources, the owner or operator shall comply with §63.163(a)(1)(ii) of subpart H of this part for light liquid pumps and §63.168(a)(1)(ii) of subpart H of this part for gas/vapor and light liquid valves.

(e) For reciprocating pumps in heavy liquid service and agitators in heavy liquid service, owners and operators are not required to comply with the requirements in §63.169 of subpart H of this

part.

(f) Reciprocating pumps in light liquid service are exempt from §§63.163 and 60.482 if recasting the distance piece or reciprocating pump replacement is required.

(g) Compressor s in hydrogen service are exempt from the requirements of paragraphs (a) and (c) of this section if an owner or operator demonstrates that a compressor is in hydrogen service.

(1) Each compressor is presumed not to be in hydrogen service unless an owner or operator demonstrates that the piece of equipment is in hydrogen service.

(2) For a piece of equipment to be considered in hydrogen service, it must be determined that the

percentage hydrogen content can be reasonably expected always to exceed 50 percent by

volume.

(i) For purposes of determining the percentage hydrogen content in the process fluid that is contained in or contacts a compressor, the owner or operator shall use either:

(A) Procedures that conform to those specified in §60.593(b)(2) of 40 par t 60, subpart GGG.Page 36 of 107

(B) Engineering judgment to demonstrate that the percentage content exceeds 50 percent by volume, provided the engineering judgment demonstrates that the content clearly exceeds 50 percent by volume.

( 1 ) When an owner or operator and the Administrator do not agree on whether a piece of equipment is in hydrogen service, the procedures in paragraph (g)(2)(i)(A) of this section shall be used to resolve the disagreement.

( 2 ) If an owner or operator determines that a piece of equipment is in h ydrogen service, the determination can be revised only by following the procedures in paragraph (g)(2)(i)(A) of this

section.

(h) Each owner or operator of a source subject to the provisions of this subpart must maintain all records for a minimum of 5 year s.

(i) Reciprocating compressors are exempt from seal requirements if recasting the distance piece or compressor replacement is required.

§ 63.649 Alternative means of emission limitation: Connectors in gas/vapor service and light liquid service.

(a) If an owner or operator elects to monitor valves according to the provisions of §63.648(c)(2)(ii), the owner or operator shall implement one of the connector monitoring programs specified in paragraphs (b), (c), or (d) of this section.

(b) Random 200 connecto r alternative . The owner or operator shall implement a random sampling program for accessible connectors of 2.0 inches nominal diameter or greater. The program does not apply to inaccessible or unsafe

- to

- monitor connectors, as defined in §63.174 of subpart H. The sampling program shall be implemented source

- wide.

(1) Within the first 12 months after the phase III compliance date specified in §63.640(h), a sample of 200 connectors shall be randomly selected and monitored using Method 21 of 40 CFR part 60, ap pendix A.

(2) The instrument reading that defines a leak is 1,000 parts per million.

(3) When a leak is detected, it shall be repaired as soon as practicable , but no later than 15 calendar days after the leak is detected except as provided in paragraph (e) of this section. A first attempt at repair shall be made no later than 5 calendar days after the leak is detected.

(4) If a leak is detected, the connector shall be monitored for leaks within the first 3 months after its repair.

(5) After conducting the i nitial survey required in paragraph (b)(1) of this section, the owner or

operator shall conduct subsequent monitoring of connectors at the frequencies specified in paragraphs (b)(5)(i) through (b)(5)(iv) of this section.Page 37 of 107

(i) If the percentage leaking conne ctors is 2.0 percent or greater, the owner or operator shall survey a random sample of 200 connectors once every 6 months.

(ii) If the percentage leaking connectors is 1.0 percent or greater but less than 2.0 percent, the owner or operator shall survey a r andom sample of 200 connectors once per year.

(iii) If the percentage leaking connectors is 0.5 percent or greater but less than 1.0 percent, the owner or operator shall survey a random sample of 200 connectors once every 2 years.

(iv) If the percentage le aking connectors is less than 0.5 percent, the owner or operator shall survey a random sample of 200 connectors once every 4 years.

(6) Physical tagging of the connectors to indicate that they are subject to the monitoring provisions is not required. Conne ctors may be identified by the area or length of pipe and need not be individually identified.

(c) Connector inspection alternative . The owner or operator shall implement a program to monitor all accessible connectors in gas/vapor service that are 2.0 inch es (nominal diameter) or greater and inspect all accessible connectors in light liquid service that are 2 inches (nominal diameter) or greater as described in paragraphs (c)(1) through (c)(7) of this section. The program does not apply to inaccessible or u nsafe

- to

- monitor connectors.

(1) Within 12 months after the phase III compliance date specified in §63.640(h), all connectors in gas/vapor service shall be monitored using Method 21 of 40 CFR part 60 appendix A. The instrument reading that defines a leak i s 1,000 parts per million.

(2) All connectors in light liquid service shall be inspected for leaks. A leak is detected if liquids are observed to be dripping at a rate greater than three drops per minute.

(3) When a leak is detected, it shall be repaired a s soon as practicable, but no later than 15

calendar days after the leak is detected except as provided in paragraph (e) of this section. A first attempt at repair shall be made no later than 5 calendar days after the leak is detected.

(4) If a leak is det ected, connectors in gas/vapor service shall be monitored for leaks within the

first 3 months after repair . Connectors in light liquid service shall be inspected for indications of leaks within the first 3 months after repair. A leak is detected if liquids are observed to be dripping at a rate greater than three drops per minute.

(5) After conducting the initial survey required in paragraphs (c)(1) and (c)(2) of this section, the owner or operator shall conduct subsequent monitoring at the frequencies speci fied in paragraphs (c)(5)(i) through (c)(5)(iii) of this section.

(i) If the percentage leaking connectors is 2.0 percent or greater, the owner or operator shall monitor or inspect, as applicable, the connectors once per year.Page 38 of 107

(ii) If the percentage leakin g connectors is 1.0 percent or greater but less than 2.0 percent, the owner or operator shall monitor or inspect, as applicable, the connectors once every 2 years.

(iii) If the percentage leaking connectors is less than 1.0 percent, the owner or operator s hall monitor or inspect, as applicable, the connectors once every 4 years.

(6) The percentage leaking connectors shall be calculated for connectors in gas/vapor service and for connectors in light liquid service. The data for the two groups of connectors s hall not be pooled for the purpose of determining the percentage leaking connectors.

(i) The percentage leaking connectors shall be calculated as follows:

% C L = [(C L −C AN )/C t +C

c )]×100

where:

% C L = Percentage leaking connectors.

C L = Number of connectors including nonrepairables, measured at 1,000 parts per million or greater, by Method 21 of 40 CFR part 60, appendix A.

C AN = Number of allowable nonrepairable connector s, as determined by monitoring, not to exceed 3 percent of the total connector population, C t
.

C t = Total number of monitored connectors, including nonrepairables, in the process unit.

C

c = Optional credit for removed connectors=0.67×net number (i.e., the total number of connectors removed minus the total added) of connectors in organic HAP service removed from the process unit after the applicability date set forth in §63.640(h)(4)(iii) for existing process units, and after the date of start

- up for new pro cess units. If credits are not taken, then C

c = 0.

(ii) Nonrepairable connectors shall be included in the calculation of percentage leaking connectors the first time the connector is identified as leaking and nonrepairable. Otherwise, a number of nonrepair able connectors up to a maximum of 1 percent per year of the total number of connectors in organic HAP service up to a maximum of 3 percent may be excluded from calculation of percentage leaking connectors for subsequent monitoring periods.

(iii) If the nu mber of nonrepairable connectors exceeds 3 percent of the total number of connectors in organic HAP service, the number of nonrepairable connectors exceeding 3 percent of the total number shall be included in the calculation of the percentage leaking conne ctors.

(7) Physical tagging of the connectors to indicate that they are subject to the monitoring provisions is not required. Connectors may be identified by the area or length of pipe and need not be individually identified.Page 39 of 107

(d) Subpart H program . The own er or operator shall implement a program to comply with the provisions in §63.174 of this part.

(e) Delay of repair of connectors for which leaks have been detected is allowed if repair is not technically feasible by normal repair techniques without a proc ess unit shutdown. Repair of this equipment shall occur by the end of the next process unit shutdown.

(1) Delay of repair is allowed for equipment that is isolated from the process and that does not remain in organic HAP service.

(2) Delay of repair for co nnectors is also allowed if:

(i) The owner or operator determines that emissions of purged material resulting from immediate repair would be greater than the fugitive emissions likely to result from delay of repair, and

(ii) When repair procedures are acco mplished, the purged material would be collected and destroyed or recovered in a control device.

(f) Any connector that is designated as an unsafe

- to

- repair connector is exempt from the requirements of paragraphs (b)(3) and (b)(4), (c)(3) and (c)(4), or (d ) of this section if:

(1) The owner or operator determines that repair personnel would be exposed to an immediate danger as a consequence of complying with paragraphs (b)(3) and (b)(4), (c)(3) and (c)(4), of this section; or

(2) The connector will be repai red before the end of the next scheduled process unit shutdown

.

(g) The owner or operator shall maintain records to document that the connector monitoring or inspections have been conducted as required and to document repair of leaking connectors as applic able.

§ 63.650 Gasoline loading rack provisions.

(a) Except as provided in paragraphs (b) through (c) of this section, each owner or operator of a Group 1 gasoline loading rack classified under Standard Industrial Classification code 2911

located within a contiguous area and under common control with a petroleum refinery shall comply with subpart R, §§63.421, 63.422(a) through (c) and (e), 63.425(a) through (c) and (i), 63.425(e) through (h), 63.427(a) and (b), and 63.428(b), (c), (g)(1), (h)(1) through ( 3), and (k).

(b) As used in this section, all terms not defined in §63.641 shall have the meaning given them in subpart A or in 40 CFR part 63, subpart R. The §63.641 definition of “affected source” applies

under this section.

(c) Gasoline loading racks re gulated under this subpart are subject to the compliance dates specified in §63.640(h).Page 40 of 107

§ 63.651 Marine tank vessel loading operation provisions.

(a) Except as provided in paragraphs (b) through (d) of this section, each owner or operator of a

marine tan k vessel loading operation located at a petroleum refinery shall comply with the requirements of §§63.560 through 63.568.

(b) As used in this section, all terms not defined in §63.641 shall have the meaning given them in subpart A or in 40 CFR part 63, sub part Y. The §63.641 definition of “affected source” applies

under this section.

(c) The notification reports under §63.567(b) are not required.

(d) The compliance time of 4 years after promulgation of 40 CFR part 63, subpart Y does not apply. The complianc e time is specified in §63.640(h)(3).

§ 63.652 Emissions averaging provisions.

(a) This section applies to owners or operators of existing sources who seek to comply with the emission standard in §63.642(g) by using emissions averaging according to §63.6 42(l) rather than following the provisions of §§63.643 through 63.647, and §§63.650 and 63.651. Existing marine tank vessel loading operations located at the Valdez Marine Terminal source may not comply with the standard by using emissions averaging.

(b) T he owner or operator shall develop and submit for approval an Implementation Plan containing all of the information required in §63.653(d) for all points to be included in an emissions average. The Implementation Plan shall identify all emission points to be included in the emissions average. This must include any Group 1 emission points to which the reference control technology (defined in §63.641) is not applied and all other emission points being controlled as part of the average.

(c) The following emiss ion points can be used to generate emissions averaging credits if control was applied after November 15, 1990 and if sufficient information is available to determine the appropriate value of credits for the emission point:

(1) Group 2 emission points;

(2) Group 1 storage vessels, Group 1 wastewater streams, Group 1 gasoline loading racks, Group 1 marine tank vessels, and Group 1 miscellaneous process vents that are controlled by a technology that the Administrator or permitting authority agrees has a higher nominal efficiency than the reference control technology. Information on the nominal efficiencies for such technologies must be submitted and approved as provided in paragraph (i) of this section; and

(3) Emission points from which emissions are reduced b y pollution prevention measures. Percentages of reduction for pollution prevention measures shall be determined as specified in paragraph (j) of this section.Page 41 of 10 7

(i) For a Group 1 emission point, the pollution prevention measure must reduce emissions more

tha n the reference control technology would have had the reference control technology been applied to the emission point instead of the pollution prevention measure except as provided in paragraph (c)(3)(ii) of this section.

(ii) If a pollution prevention mea sure is used in conjunction with other controls for a Group 1 emission point, the pollution prevention measure alone does not have to reduce emissions more than the reference control technology, but the combination of the pollution prevention measure

and o ther controls must reduce emissions more than the reference control technology would have had it been applied instead.

(d) The following emission points cannot be used to generate emissions averaging credits:

(1) Emission points already controlled on or be fore November 15, 1990 unless the level of

control is increased after November 15, 1990, in which case credit will be allowed only for the increase in control after November 15, 1990;

(2) Group 1 emission points that are controlled by a reference control t echnology unless the reference control technology has been approved for use in a different manner and a higher nominal efficiency has been assigned according to the procedures in paragraph (i) of this section. For example, it is not allowable to claim that an internal floating roof meeting only the specifications stated in the reference control technology definition in §63.641 (i.e., that meets the specifications of §63.119(b) of subpart G but does not have controlled fittings per §63.119 (b)(5) and (b)(6) of subpart G) applied to a storage vessel is achieving greater than 95 percent control;

(3) Emission points on shutdown process units. Process units that are shut down cannot be used to generate credits or debits;

(4) Wastewater that is not process wastewa ter or wastewater streams treated in biological treatment units. These two types of wastewater cannot be used to generate credits or debits. Group 1 wastewater streams cannot be left undercontrolled or uncontrolled to generate debits. For the purposes of t his section, the terms “wastewater” and “wastewater stream” are used to mean process wastewater; and

(5) Emission points controlled to comply with a State or Federal rule other than this subpart,

unless the level of control has been increased after Novembe r 15, 1990 above what is required by the other State or Federal rule. Only the control above what is required by the other State or Federal rule will be credited. However, if an emission point has been used to generate emissions averaging credit in an appr oved emissions average, and the point is subsequently made subject to a State or Federal rule other than this subpart, the point can continue to generate emissions averaging credit for the purpose of complying with the previously approved average.

(e) For all points included in an emissions average , the owner or operator shall:Page 42 of 107

(1) Calculate and record monthly debits for all Group 1 emission points that are controlled to a level less stringent than the reference control technology for those emission points. Equations in paragraph (g) of this section shall be used to calculate debits.

(2) Calculate and record monthly credits for all Group 1 or Group 2 emission points that are overcontrolled to compensate for the debits. Equations in paragraph (h) of this sect ion shall be used to calculate credits. Emission points and controls that meet the criteria of paragraph (c) of this section may be included in the credit calculation, whereas those described in paragraph (d)

of this section shall not be included.

(3) Demo nstrate that annual credits calculated according to paragraph (h) of this section are greater than or equal to debits calculated for the same annual compliance period according to paragraph (g) of this section.

(i) The initial demonstration in the Implemen tation Plan that credit

- generating emission points will be capable of generating sufficient credits to offset the debits from the debit

- generating emission points must be made under representative operating conditions.

(ii) After the compliance date, actua l operating data will be used for all debit and credit

calculations

.

(4) Demonstrate that debits calculated for a quarterly (3

- month) period according to paragraph (g) of this section are not more than 1.30 times the credits for the same period calculated according to paragraph (h) of this section. Compliance for the quarter shall be determined based on the ratio of credits and debits from that quarter, with 30 percent more debits than credits allowed on a quarterly basis.

(5) Record and report quarterly an d annual credits and debits in the Periodic Reports as specified in §63.655(g)(8). Every fourth Periodic Report shall include a certification of compliance with the emissions averaging provisions as required by §63.655(g)(8)(iii).

(f) Debits and credits sh all be calculated in accordance with the methods and procedures specified in paragraphs (g) and (h) of this section, respectively, and shall not include emissions from the following:

(1) More than 20 individual emission points. Where pollution prevention m easures (as specified in paragraph (j)(1) of this section) are used to control emission points to be included in an emissions average, no more than 25 emission points may be included in the average. For example, if two emission points to be included in an emissions average are controlled by pollution prevention measures, the average may include up to 22 emission points.

(2) Periods of startup, shutdown, and malfunction as described in the source ’ s startup, shutdown, and malfunction plan required by §63.6(e) (3) of subpart A of this part.Page 43 of 107

(3) For emission points for which continuous monitors are used, periods of excess emissions as defined in §63.655(g)(6)(i). For these periods, the calculation of monthly credits and debits shall be adjusted as specified in pa ragraphs (f)(3)(i) through (f)(3)(iii) of this section.

(i) No credits would be assigned to the credit

- generating emission point.

(ii) Maximum debits would be assigned to the debit

- generating emission point.

(iii) The owner or operator may use the procedur es in paragraph (l) of this section to demonstrate to the Administrator that full or partial credits or debits should be assigned.

(g) Debits are generated by the difference between the actual emissions from a Group 1 emission point that is uncontrolled or is controlled to a level less stringent than the reference control technology, and the emissions allowed for Group 1 emission point. Debits shall be calculated as

follows:

(1) The overall equation for calculating sourcewide debits is:

where:

Debits and all terms of the equation are in units of megagrams per month, and

EPV iACTUAL = Emissions from each Group 1 miscellaneous process vent i that is uncontrolled or

is controlled to a level less stringent than the reference control technology. This is calculated according to paragraph (g)(2) of this section.

(0.02) EPV iu = Emissions from each Group 1 miscellaneous process vent i if the reference control technology had be en applied to the uncontrolled emissions, calculated according to paragraph (g)(2) of this section.

ES iACTUAL = Emissions from each Group 1 storage vessel i that is uncontrolled or is controlled to a level less stringent than the reference control technolo gy. This is calculated according to paragraph (g)(3) of this section.

(0.05) ES iu = Emissions from each Group 1 storage vessel i if the reference control technology had been applied to the uncontrolled emissions, calculated according to paragraph (g)(3) of this

section.Page 44 of 107

EGLR iACTUAL = Emissions from each Group 1 gasoline loading rack i that is uncontrolled or is controlled to a level less stringent than the reference control technology. This is calculated according to paragraph (g)(4) of this section.

EGLR ic = Emissions from each Group 1 gasoline loading rack i if the reference control technology had been applied to the uncontrolled emissions. This is calculated according to paragraph (g)(4) of this section.

EMV ACTUAL = Emissions from each Group 1 marine tank vessel i that is uncontrolled or is controlled to a level less stringent than the reference control technology. This is calculated according to paragraph (g)(5) of this section.

(0.03) EMV iu = Emissions from each Group 1 marine tank vessel i if the refere nce control technology had been applied to the uncontrolled emissions calculated according to paragraph (g)(5) of this section.

n = The number of Group 1 emission points being included in the emissions average. The value of n is not necessarily the same fo r each kind of emission point.

(2) Emissions from miscellaneous process vents shall be calculated as follows:

(i) For purposes of determining miscellaneous process vent stream flow rate, organic HAP concentrations, and temperature, the sampling site shall be after the final product recovery device, if any recovery devices are present; before any control device (for miscellaneous process vents, recovery devices shall not be considered control devices); and before discharge to the atmosphere. Method 1 or 1A o f part 60, appendix A shall be used for selection of the sampling

site.

(ii) The following equation shall be used for each miscellaneous process vent i to calculate

EPV iu :

where:

EPV iu = Uncontrolled process vent emission rate from miscellaneous process vent i, megagrams per month.

Q = Vent stream flow rate, dry standard cubic meters per minute, measured using Methods 2, 2A, 2C, or 2D of part 60 appendix A, as appr opriate.

h = Monthly hours of operation during which positive flow is present in the vent, hours per

month.Page 45 of 107

C

j = Concentration , parts per million by volume, dry basis, of organic HAP j as measured by Method 18 of part 60 appendix A.

M

j = Molecular weight o f organic HAP j, gram per gram

- mole.

n = Number of organic HAP ’ s in the miscellaneous process vent stream.

(A) The values of Q, C j , and M j shall be determined during a performance test conducted under representative operating conditions. The values of Q, C j , and M j shall be established in the Notification of Compliance Status report and must be updated as provided in paragraph (g)(2)(ii)(B) of this section.

(B) If there is a change in capacity utilization other than a change in monthly operating hours, or

i f any other change is made to the process or product recovery equipment or operation such that the previously measured values of Q, C j , and M j are no longer representative, a new performance test shall be conducted to determine new representative values of Q, C j , and M j . These new values shall be used to calculate debits and credits from the time of the change forward, and the new values shall be reported in the next Periodic Report.

(iii) The following procedures and equations shall be used to calculate EP V iACTUAL :

(A) If the vent is not controlled by a control device or pollution prevention measure, EPV iACTUAL = EPV iu , where EPV iu is calculated according to the procedures in paragraphs (g)(2)(i) and (g)(2)(ii) of this section.

(B) If the vent is controlled using a control device or a pollution prevention measure achieving

less than 98

- percent reduction,

( 1 ) The percent reduction shall be measured according to the pr ocedures in §63.116 of subpart G if a combustion control device is used. For a flare meeting the criteria in §63.116(a) of subpart G, or a boiler or process heater meeting the criteria in §63.645(d) of this subpart or §63.116(b) of subpart G, the percentag e of reduction shall be 98 percent. If a noncombustion control device is used, percentage of reduction shall be demonstrated by a performance test at the inlet and outlet

of the device , or, if testing is not feasible, by a control design evaluation and doc umented engineering calculations.

( 2 ) For determining debits from miscellaneous process vents, product recovery devices shall not be considered control devices and cannot be assigned a percentage of reduction in calculating

EPV iACTUAL . The sampling site fo r measurement of uncontrolled emissions is after the final product recovery device.Page 46 of 107

( 3 ) Procedures for calculating the percentage of reduction of pollution prevention measures are specified in paragraph (j) of this section.

(3) Emissions from storage vesse ls shall be calculated as specified in §63.150(g)(3) of subpart G.

(4) Emissions from gasoline loading racks shall be calculated as follows:

(i) The following equation shall be used for each gasoline loading rack i to calculate EGLR iu :

where:

EGLR iu = Uncontrolled transfer HAP emission rate from gasoline loading rack i, megagrams per

month

S = Saturation factor, dimensionless (see table 33 of subpart G).

P = Weight ed average rack partial pressure of organic HAP ’ s transferred at the rack during the month, kilopascals.

M = Weighted average molecular weight of organic HAP ’ s transferred at the gasoline loading rack during the month, gram per gram

- mole.

G = Monthly volum e of gasoline transferred from gasoline loading rack, liters per month.

T = Weighted rack bulk liquid loading temperature during the month, degrees kelvin (degrees Celsius °C + 273).

(ii) The following equation shall be used for each gasoline loading rack i to calculate the weighted average rack partial pressure:

where:

P

j = Maximum true vapor pressure of individual organic HAP transferred at the rack, kilopascals.

G = Monthly volume of organic HAP transferred, liters per month, andPage 47 of 107

G

j = Monthly volume of individual organic HAP transferred at the gasoline loading rack, lite rs per month.

n = Number of organic HAP ’ s transferred at the gasoline loading rack.

(iii) The following equation shall be used for each gasoline loading rack i to calculate the weighted average rack molecular weight:

where:

M

j = Molecular weight of individual organic HAP transferred at the rack, gram per gram

- mole.

G, G j , and n are as defined in paragraph (g)(4)(ii) of this section.

(iv) The following equation shal l be used for each gasoline loading rack i to calculate the monthly weighted rack bulk liquid loading temperature:

T

j = Average annual bulk temperature of individ ual organic HAP loaded at the gasoline loading rack, kelvin (degrees Celsius °C+273).

G, G j , and n are as defined in paragraph (g)(4)(ii) of this section.

(v) The following equation shall be used to calculate EGLR ic :

G is as defined in paragraph (g)(4)(ii) of this section.

(vi) The following procedures and equations shall be used to calculate EGLR iACTUAL :

(A) If the gasoline loading rack is not controlled, EGLR iACT UAL = EGLR iu , where EGLR iu is calculated using the equations specified in paragraphs (g)(4)(i) through (g)(4)(iv) of this section.

(B) If the gasoline loading rack is controlled using a control device or a pollution prevention measure not achieving the req uirement of less than 10 milligrams of TOC per liter of gasoline loaded,Page 48 of 107

( 1 ) The percent reduction for a control device shall be measured according to the procedu res and test methods specified in §63.128(a) of subpart G. If testing is not feasible, the percentage of reduction shall be determined through a design evaluation according to the procedures specified in §63.128(h) of subpart G.

( 2 ) Procedures for calculat ing the percentage of reduction for pollution prevention measures are specified in paragraph (j) of this section.

(5) Emissions from marine tank vessel loading shall be calculated as follows:

(i) The following equation shall be used for each marine tank ve ssel i to calculate EMV iu :

where:

EMV iu = Uncontrolled marine tank vessel HAP emission rate from marine tank vessel i, megagrams per month.

Q i = Quantity of commo dity loaded (per vessel type), liters.

F i = Emission factor, megagrams per liter.

P i = Percent HAP

.

m = Number of combinations of commodities and vessel types loaded.

Emission factors shall be based on test data or emission estimation procedures specified in §63.565(l) of subpart Y.

(ii) The following procedures and equations shall be used to calculate EMV iACTUAL :

(A) If the marine tank vessel is not controlled, EMV iACTUAL = EMV iu , where EMV iu is calculated using the equations specified in paragraph (g)(5)( i) of this section.

(B) If the marine tank vessel is controlled using a control device or a pollution prevention measure achieving less than 97

- percent reduction,Page 49 of 107

( 1 ) The percent reduction for a control device shall be measured according to the procedures and test methods specified in §63.565(d) of subpart Y. If testing is not feasible, the percentage of reduction shall be determined through a design evaluation acc ording to the procedures specified in §63.128(h) of subpart G.

( 2 ) Procedures for calculating the percentage of reduction for pollution prevention measures are specified in paragraph (j) of this section.

(h) Credits are generated by the difference between emissions that are allowed for each Group 1 and Group 2 emission point and the actual emissions from a Group 1 or Group 2 emission point that has been controlled after November 15, 1990 to a level more stringent than what is required by this subpart or any other State or Federal rule or statute. Credits shall be calculated as follows:

(1) The overall equation for calculating sourcewide credits is:

where:

Credits an d all terms of the equation are in units of megagrams per month, the baseline date is November 15, 1990, and

D = Discount factor = 0.9 for all credit

- generating emission points except those controlled by a pollution prevention measure, which will not be di scounted.

EPV1 iACTUAL = Emissions for each Group 1 miscellaneous process vent i that is controlled to a level more stringent than the reference control technology, calculated according to paragraph (h)(2) of this section.

(0.02) EPV1 iu = Emissions from eac h Group 1 miscellaneous process vent i if the reference control technology had been applied to the uncontrolled emissions. EPV1 iu is calculated according to paragraph (h)(2) of this section.Page 50 of 107

EPV2 iBASE = Emissions from each Group 2 miscellaneous process ven t; at the baseline date, as calculated in paragraph (h)(2) of this section.

EPV2 iACTUAL = Emissions from each Group 2 miscellaneous process vent that is controlled, calculated according to paragraph (h)(2) of this section.

ES1 iACTUAL = Emissions from each Group 1 storage vessel i that is controlled to a level more stringent than the reference control technology, calculated according to paragraph (h)(3) of this

section.

(0.05) ES1 iu = Emissions from each Group 1 storage vessel i if the reference control tech nology had been applied to the uncontrolled emissions. ES1 iu is calculated according to paragraph (h)(3)

of this section.

ES2 iACTUAL = Emissions from each Group 2 storage vessel i that is controlled, calculated according to paragraph (h)(3) of this section

.

ES2 iBASE = Emissions from each Group 2 storage vessel i at the baseline date, as calculated in paragraph (h)(3) of this section.

EGLR1 iACTUAL = Emissions from each Group 1 gasoline loading rack i that is controlled to a level more stringent than the refe rence control technology, calculated according to paragraph (h)(4) of this section.

EGLR ic = Emissions from each Group 1 gasoline loading rack i if the reference control technology had been applied to the uncontrolled emissions. EGLR iu is calculated accord ing to paragraph (h)(4) of this section.

EGRL2 iACTUAL = Emissions from each Group 2 gasoline loading rack i that is controlled, calculated according to paragraph (h)(4) of this section.

EGLR2 iBASE = Emissions from each Group 2 gasoline loading rack i at th e baseline date, as calculated in paragraph (h)(4) of this section.

EMV1 iACTUAL = Emissions from each Group 1 marine tank vessel i that is controlled to a level more stringent than the reference control technology, calculated according to paragraph (h)(4) of

this section.

(0.03)EMV1 iu = Emissions from each Group 1 marine tank vessel i if the reference control technology had been applied to the uncontrolled emissions. EMV1 iu is calculated according to paragraph (h)(5) of this section.

EMV2 iACTUAL = Emissions from each Group 2 marine tank vessel i that is controlled, calculated according to paragraph (h)(5) of this section.Page 51 of 107

EMV2 iBASE = Emissions from each Group 2 marine tank vessel i at the baseline date, as calculated in paragraph (h)(5) of this section.

EWW1 iACTUAL = Emissions from each Group 1 wastewater stream i that is controlled to a level more stringent than the reference control technology, calculated according to paragraph (h)(6) of

this section.

EWW1 ic = Emissions from each Group 1 wastewater stream i if the reference control technology had been applied to the uncontrolled emissions, calculated according to paragraph (h)(6) of this

section.

EWW2 iACTUAL = Emissions from each Group 2 wastewater stream i that is controlled, calculated according to paragra ph (h)(6) of this section.

EWW2 iBASE = Emissions from each Group 2 wastewater stream i at the baseline date, calculated according to paragraph (h)(6) of this section.

n = Number of Group 1 emission points included in the emissions average. The value of n i s not necessarily the same for each kind of emission point.

m = Number of Group 2 emission points included in the emissions average. The value of m is not necessarily the same for each kind of emission point.

(i) For an emission point controlled using a re ference control technology, the percentage of reduction for calculating credits shall be no greater than the nominal efficiency associated with the reference control technology, unless a higher nominal efficiency is assigned as specified in paragraph (h)(1 )(ii) of this section.

(ii) For an emission point controlled to a level more stringent than the reference control technology , the nominal efficiency for calculating credits shall be assigned as described in paragraph (i) of this section. A reference contro l technology may be approved for use in a different manner and assigned a higher nominal efficiency according to the procedures in paragraph (i) of this section.

(iii) For an emission point controlled using a pollution prevention measure, the nominal

effic iency for calculating credits shall be determined as described in paragraph (j) of this section.

(2) Emissions from process vents shall be determined as follows:

(i) Uncontrolled emissions from miscellaneous process vents, EPV1 iu , shall be calculated

accor ding to the procedures and equation for EPV iu in paragraphs (g)(2)(i) and (g)(2)(ii) of this

section.

(ii) Actual emissions from miscellaneous process vents controlled using a technology with an approved nominal efficiency greater than 98 percent or a poll ution prevention measure achievingPage 52 of 107

greater than 98 percent emission reduction, EPV1 iACTUAL , shall be calculated according to the following equation:

(iii) The fol lowing procedures shall be used to calculate actual emissions from Group 2 process vents, EPV2 iACTUAL :

(A) For a Group 2 process vent controlled by a control device, a recovery device applied as a pollution prevention project, or a pollution prevention mea sure, if the control achieves a percentage of reduction less than or equal to a 98 percent reduction,

( 1 ) EPV2 iu shall be calculated according to the equations an d procedures for EPV iu in paragraphs (g)(2)(i) and (g)(2)(ii) of this section except as provided in paragraph (h)(2)(iii)(A)( 3 ) of this

section.

( 2 ) The percentage of reduction shall be calculated according to the procedures in paragraphs (g)(2)(iii)(B)( 1 ) through (g)(2)(iii)(B)( 3 ) of this section except as provided in paragraph (h)(2)(iii)(A)( 4 ) of this section.

( 3 ) If a recovery device was added as part of a pollution prevention project, EPV2 iu shall be calculated prior to that recovery device. The equati on for EPV iu in paragraph (g)(2)(ii) of this

section shall be used to calculate EPV2 iu ; however, the sampling site for measurement of vent stream flow rate and organic HAP concentration shall be at the inlet of the recovery device.

( 4 ) If a recovery device was added as part of a pollution prevention project, the percentage of reduction shall be demonstrated by conducting a performance test at the inlet and outlet of that recovery device.

(B) For a Group 2 process vent controlled using a technology with an a pproved nominal efficiency greater than a 98 percent or a pollution prevention measure achieving greater than 98 percent reduction,

(iv) Emissions from Group 2 pr ocess vents at baseline , EPV2 iBASE , shall be calculated as follows:

(A) If the process vent was uncontrolled on November 15, 1990, EPV2 iBASE = EPV2 iu , and shall be calculated according to the procedures and equation for EPV iu in paragraphs (g)(2)(i) and (g )(2)(ii) of this section.Page 53 of 107

(B) If the process vent was controlled on November 15, 1990,

where EPV2 iu is calculated according to the procedures and equation for EPV iu in paragraphs (g)(2)(i) and (g)(2)(ii) of this section. The percentage of reduction shall be calculated according to the procedures specified in paragraphs (g)(2)(iii)(B)( 1 ) through (g)(2)(iii)(B)( 3 ) of this

section.

(C) If a recovery device was added t o a process vent as part of a pollution prevention project initiated after November 15, 1990, EPV2 iBASE = EPV2 iu , where EPV2 iu is calculated according to paragraph (h)(2)(iii)(A)( 3 ) of this section.

(3) Emissions from storage vessels shall be determined as specified in §63.150(h)(3) of subpart G, except as follows:

(i) All references to §63.119(b) in §63.150(h)(3) of subpart G shall be replaced with: §63.119 (b) or §63.119(b) except for §63.119(b)(5) and (b)(6).

(ii) All references to §63.119(c) in § 63 .150( h)(3) of subpart G shall be replaced with: §63.119(c) or §63.119(c) except for §63.119(c)(2).

(iii) All references to §63.119(d) in §63.150(h)(3) of subpart G shall be replaced with: §63.119(d) or §63.119(d) except for §63.119(d)(2).

(4) Emissions from gas oline loading racks shall be determined as follows:

(i) Uncontrolled emissions from Group 1 gasoline loading racks , EGLR1 iu , shall be calculated according to the procedures and equations for EGLR iu as described in paragraphs (g)(4)(i) through (g)(4)(iv) of this section.

(ii) Emissions from Group 1 gasoline loading racks if the reference control technology had been applied, EGLR ic , shall be calculated according to the procedures and equations in paragraph (g)(4)(v) of this section.

(iii) Actual emissions fro m Group 1 gasoline loading racks controlled to less than 10 milligrams of TOC per liter of gasoline loaded; EGLR iACTUAL , shall be calculated according to the following equation:

(iv) The following procedures shall be used to calculate actual emissions from Group 2 gasoline loading racks, EGLR2 iACTUAL :Page 54 of 107

(A) For a Group 2 gasoline loading rack controlled by a control device or a pollution prevention measure achieving emissions reduction but where emissions are greater than the 10 milligrams of TOC per liter of gasoline loaded requirement,

( 1 ) EGLR2 iu shall be calculated accord ing to the equations and procedures for EGLR iu in paragraphs (g)(4)(i) through (g)(4)(iv) of this section.

( 2 ) The percentage of reduction shall be calculated according to the procedures in paragraphs (g)(4)(vi)(B)( 1 ) and (g)(4)(vi)(B)( 2 ) of this section.

(B) For a Group 2 gasoline loading rack controlled by using a technology with an approved nominal efficiency greater than 98 percent or a pollution prevention measure achieving greater

than a 98

- percent reduction,

(v) Emissions from Group 2 gasoline loading racks at baseline , EGLR2 iBASE , shall be calculated

as follows:

(A) If the gasoline loading rack was uncontrolled on November 15, 1990, EGLR2 iBASE = EGLR2 iu , and shall be calculated according to the procedures and equations for EGLR iu in paragraphs (g)(4)(i) through (g)(4)(iv) of this section.

(B) If the gasoline loading rack was controlled on November 15, 1990,

where EGLR2 iu is calculated according to the procedures and equations for EGLR iu in paragraphs (g)(4)(i) through (g)(4)(iv) of this section. Percentage of reduction shall be calculated according to the procedur es i n paragraphs (g)(4)(vi)(B)( 1 ) and (g)(4)(vi)(B)( 2 ) of this section.

(5) Emissions from marine tank vessels shall be determined as follows:

(i) Uncontrolled emissions from Group 1 marine tank vessels, EMV1 iu , shall be calculated according to the procedures and equations for EMV iu as described in paragraph (g)(5)(i) of this

section.

(ii) Actual emissions from Group 1 marine tank vessels controlled using a technology or pollution prevention measure with an approved nominal efficiency greater than 97 percent,

E MV iACTUAL , shall be calculated according to the following equation:Page 55 of 107

(iii) The following procedures shall be used to calculate actual emissions from Group 2 marine tank vessels, EMV2 iACTUAL :

(A) For a Group 2 marine tank vessel controlled by a control device or a pollution prevention measure achieving a percentage of reduction less than or equal to 97 percent reduction,

( 1 ) EMV2 iu shall be calculated according to the equations and procedures for EMV iu in paragraph (g)(5)(i) of this section.

( 2 ) The percentage of reduction shall be calculated according to the procedures in pa ragraphs (g)(5)(ii)(B)( 1 ) and (g)(5)(ii)(B)( 2 ) of this section.

(B) For a Group 2 marine tank vessel controlled using a technology or a pollution prevention measure with an approved nominal efficiency greater than 97 percent,

(iv) Emissions from Group 2 marine tank vessels at baseline, EMV2 iBASE , shall be calculated as

follows:

(A) If the marine terminal was uncontrolled on November 15, 1990, EMV2 iBASE equals EMV2 i u , and shall be calculated according to the procedures and equations for EMV iu in paragraph (g)(5)(i) of this section.

(B) If the marine tank vessel was controlled on November 15, 1990

,

where EMV2 iu is calculated according to the procedures and equations for EMV iu in paragraph (g)(5)(i) of this section. Percentage of reduction shall be calculated according to the procedures in paragraphs (g)(5)(ii)(B)( 1 ) and (g)(5) (ii)(B)( 2 ) of this section.

(6) Emissions from wastewater shall be determined as follows:

(i) For purposes of paragraphs (h)(4)(ii) through (h)(4)(vi) of this section, the following terms will have the meaning given them in paragraphs (h)(6)(i)(A) through (h)(6)(i)(C) of this section.Page 56 of 107

(A) Correctly suppressed means that a wastewater stream is being managed according to the requirements of §§61.343 through 61.347 or §61.342(c)(l)(iii) of 40 CFR part 61, subpart FF, as applicable, and the emissions from the w aste management units subject to those requirements are routed to a control device that reduces HAP emissions by 95 percent or greater.

(B) Treatment process has the meaning given in §61.341 of 40 CFR part 61, subpart FF except

that it does not include bio logical treatment units.

(C) Vapor control device means the control device that receives emissions vented from a

treatment process or treatment processes.

(ii) The following equation shall be used for each wastewater stream i to calculate EWW ic :

where:

EWW ic = Monthly wastewater stream emission rate if wastewater stream i were controlled by the reference control technology, megagrams per month.

Q i = Average flow ra te for wastewater stream i, liters per minute.

H i = Number of hours during the month that wastewater stream i was generated, hours per

month.

Fr
m =Fraction removed of organic HAP m in wastewater, from table 7 of this subpart,

dimensionless.

Fe
m =Fraction e mitted of organic HAP m in wastewater from table 7 of this subpart,

dimensionless.

s = Total number of organic HAP ’ s in wastewater stream i.

HAP im = Average concentration of organic HAP m in wastewater stream i, parts per million by weight.

(A) HAP im shall be determined for the point of generation or at a location downstream of the point of generation. Wastewater samples shall be collected using the sampling procedures specified in Method 25D of 40 CFR part 60, appendix A. Where feasible, samples shall be t aken from an enclosed pipe prior to the wastewater being exposed to the atmosphere. When sampling from an enclosed pipe is not feasible, a minimum of three representative samples shall be collected in a manner to minimize exposure of the sample to the atmo sphere and loss of organic

HAP ’ s prior to sampling. The samples collected may be analyzed by either of the following procedures:Page 57 of 107

( 1 ) A test method or results from a test method that measures organic HAP concentrations in the wastewater, and that has been v alidated pursuant to section 5.1 or 5.3 of Method 301 of appendix A of this part may be used; or

( 2 ) Method 305 of appendix A of this part may be used to determine C im , the average volatile organic HAP concentration of organic HAP m in wastewater stream i, and then HAP im may be calculated using the following equation: HAP im = C im /Fm

m , where Fm

m for organic HAP m is obtained from table 7 of this subpart.

(B) Values for Q i , HAP im , and C im shall be determined during a performance test conducted under represent ative conditions. The average value obtained from three test runs shall be used. The values of Q i , HAP im , and C im shall be established in the Notification of Compliance Status report and must be updated as provided in paragraph (h)(6)(i)(C) of this section

.

(C) If there is a change to the process or operation such that the previously measured values of Q i , HAP im , and C im are no longer representative, a new performance test shall be conducted to determine new representative values of Q i , HAP im , and C im . Thes e new values shall be used to calculate debits and credits from the time of the change forward, and the new values shall be reported in the next Periodic Report.

(iii) The following equations shall be used to calculate EWW1 iACTUAL for each Group 1

wastewat er stream i that is correctly suppressed and is treated to a level more stringent than the reference control technology.

(A) If the Group 1 wastewater stream i is controlled using a treatment process or series of treatment processes with an approved nomina l reduction efficiency for an individually speciated HAP that is greater than that specified in table 7 of this subpart, and the vapor control device achieves a percentage of reduction equal to 95 percent, the following equation shall be used:

Where:

EWW iACTUAL = Monthly wastewater stream emission rate if wastewater stream i is treated to a level more stringent than the reference control technology, megagrams per m onth.

PR im = The efficiency of the treatment process, or series of treatment processes, that treat wastewater stream i in reducing the emission potential of organic HAP m in wastewater, dimensionless, as calculated by:

Where:Page 58 of 107

HAP im

- in = Average concentration of organic HAP m, parts per million by weight, as defined and determined according to paragraph (h)(6)(ii)(A) of this section, in the wastewater entering the

f irst treatment process in the series.

HAP im

- out = Average concentration of organic HAP m, parts per million by weight, as defined and determined according to paragraph (h)(6)(ii)(A) of this section, in the wastewater exiting the last treatment process in t he series.

All other terms are as defined and determined in paragraph (h)(6)(ii) of this section.

(B) If the Group 1 wastewater stream i is not controlled using a treatment process or series of treatment processes with an approved nominal reduction efficie ncy for an individually speciated HAP that is greater than that specified in table 7 of this subpart, but the vapor control device has an approved nominal efficiency greater than 95 percent, the following equation shall be used:

Where:

Nominal efficiency = Approved reduction efficiency of the vapor control device, dimensionless, as determined according to the procedures in §63.652(i).

A

m = The efficiency of the tre atment process, or series of treatment processes, that treat wastewater stream i in reducing the emission potential of organic HAP m in wastewater,

dimensionless.

All other terms are as defined and determined in paragraphs (h)(6)(ii) and (h)(6)(iii)(A) of this

section.

( 1 ) If a steam stripper meeting the specifications in the definition of reference control technology for wastewater is used, A

m shall be equal to the value of Fr

m given in table 7 of this subpart.

( 2 ) If an alternative control device is used, the percentage of reduction must be determined using the equation and methods specified in paragraph (h)(6)(iii)(A) of this section for determining

PR im . If the value of PR im is greater than or equal to the value of Fr

m given in table 7 of this subpart, t hen A

m equals Fr

m unless a higher nominal efficiency has been approved. If a higher nominal efficiency has been approved for the treatment process, the owner or operator shall

determine EWW1 iACTUAL according to paragraph (h)(6)(iii)(B) of this section rath er than paragraph (h)(6)(iii)(A) of this section. If PR im is less than the value of FR

m given in table 7 of this subpart, emissions averaging shall not be used for this emission point.

(C) If the Group 1 wastewater stream i is controlled using a treatment process or series of treatment processes with an approved nominal reduction efficiency for an individually speciated hazardous air pollutant that is greater than that specified in table 7 of this subpart, and the vaporPage 59 of 107

control device has an approved nomina l efficiency greater than 95 percent, the following equation shall be used:

where all terms are as defined and determined in paragraphs (h)(6)(ii) and (h)(6)(iii) (A) of this

section.

(iv) The following equation shall be used to calculate EWW2 iBASE for each Group 2 wastewater stream i that on November 15, 1990 was not correctly suppressed or was correctly suppressed

but not treated:

Where:

EWW2 iBASE = Monthly wastewater stream emission rate if wastewater stream i is not correctly suppressed , megagrams per month.

Q i , H i , s, Fe
m , and HAP im are as defined and determined accordi ng to paragraphs (h)(6)(ii) and (h)(6)(iii)(A) of this section.

(v) The following equation shall be used to calculate EWW2 iBASE for each Group 2 wastewater stream i on November 15, 1990 was correctly suppressed. EWW2 iBASE shall be calculated as if

the cont rol methods being used on November 15, 1990 are in place and any control methods applied after November 15, 1990 are ignored. However, values for the parameters in the equation shall be representative of present production levels and stream properties.

where R i is calculated according to paragraph (h)(6)(vii) of this section and all other terms are as defined and determined according to paragraphs (h)(6)(ii) and (h )(6)(iii)(A) of this section.

(vi) For Group 2 wastewater streams that are correctly suppressed, EWW2 iACTUAL shall be calculated according to the equation for EWW2 iBASE in paragraph (h)(6)(v) of this section.

EWW2 iACTUAL shall be calculated with all contro l methods in place accounted for.

(vii) The reduction efficiency, R i , of the vapor control device shall be demonstrated according to the following procedures:

(A) Sampling sites shall be selected using Method 1 or 1A of 40 CFR part 60, appendix A, as

appro priate.Page 60 of 107

(B) The mass flow rate of organic compounds entering and exiting the control device shall be

determined as follows:

( 1 ) The time period for the test shall not be less than 3 hours during which at least three runs are

conducted.

( 2 ) A run shall cons ist of a 1

- hour period during the test. For each run:

( i ) The volume exhausted shall be determined using Methods 2, 2A, 2C, or 2D of 40 CFR part 60 appendix A, as appropriate;

( ii ) The organic concentration in the vent stream entering and exiting the contr ol device shall be determined using Method 18 of 40 CFR part 60, appendix A. Alternatively, any other test method validated according to the procedures in Method 301 of appendix A of this part may be

used.

( 3 ) The mass flow rate of organic compounds enteri ng and exiting the control device during each

run shall be calculated as follows:

Where:

E
a = Mass flow rate of organic compounds exiting the control device, kilo grams per hour.

E b = Mass flow rate of organic compounds entering the control device, kilograms per hour.

V ap = Average volumetric flow rate of vent stream exiting the control device during run p at standards conditions, cubic meters per hour.

V bp = Averag e volumetric flow rate of vent stream entering the control device during run p at standards conditions, cubic meters per hour.

p = Run.

m = Number of runs.

C aip = Concentration of organic compound i measured in the vent stream exiting the control

device du ring run p as determined by Method 18 of 40 CFR part 60 appendix A, parts per million by volume on a dry basis.Page 61 of 107

C bip = Concentration of organic compound i measured in the vent stream entering the control device during run p as determined by Method 18 of 40 CFR part 60, appendix A, parts per million by volume on a dry basis.

MW i = Molecular weight of organic compound i in the vent stream, kilograms per kilogram

mole.

n = Number of organic compounds in the vent stream.

0.0416 = Conversion factor for molar vol ume, kilograms

- mole per cubic meter at 293 kelvin and 760 millimeters mercury absolute.

(C) The organic reduction efficiency for the control device shall be calculated as follows:

Where:

R = Total organic reduction efficiency for the control device, percentage.

E b = Mass flow rate of organic compounds entering the control device, kilograms per hour.

E
a = Mass flow rate of organic compounds exiting the control devic e, kilograms per hour.

(i) The following procedures shall be followed to establish nominal efficiencies. The procedures in paragraphs (i)(1) through (i)(6) of this section shall be followed for control technologies that are different in use or design from the reference control technologies and achieve greater percentages of reduction than the percentages of efficiency assigned to the reference control technologies in §63.641.

(1) In those cases where the owner or operator is seeking permission to take credi t for use of a control technology that is different in use or design from the reference control technology, and the different control technology will be used in more than three applications at a single plant site, the owner or operator shall submit the inf ormation specified in paragraphs (i)(1)(i) through (i)(1)(iv) of this section to the Administrator in writing:

(i) Emission stream characteristics of each emission point to which the control technology is or will be applied including the kind of emission p oint, flow, organic HAP concentration, and all other stream characteristics necessary to design the control technology or determine its performance;

(ii) Description of the control technology including design specifications;Page 62 of 107

(iii) Documentation demonstrati ng to the Administrator ’ s satisfaction the control efficiency of the control technology. This may include performance test data collected using an appropriate EPA method or any other method validated according to Method 301 of appendix A of this part.

If i t is infeasible to obtain test data, documentation may include a design evaluation and calculations. The engineering basis of the calculation procedures and all inputs and assumptions made in the calculations shall be documented; and

(iv) A description of the parameter or parameters to be monitored to ensure that the control technology will be operated in conformance with its design and an explanation of the criteria used for selection of that parameter (or parameters).

(2) The Administrator shall determine within 120 calendar days whether an application presents sufficient information to determine nominal efficiency. The Administrator reserves the right to request specific data in addition to the items listed in paragraph (i)(1) of this section.

(3) The Adm inistrator shall determine within 120 calendar days of the submittal of sufficient data whether a control technology shall have a nominal efficiency and the level of that nominal efficiency. If, in the Administrator ’ s judgment, the control technology achie ves a level of emission reduction greater than the reference control technology for a particular kind of emission point, the Administrator will publish a Federal Register notice establishing a nominal efficiency for the control technology.

(4) The Admini strator may grant conditional permission to take emission credits for use of the control technology on requirements that may be necessary to ensure operation and maintenance to achieve the specified nominal efficiency.

(5) In those cases where the owner or operator is seeking permission to take credit for use of a

control technology that is different in use or design from the reference control technology and the different control technology will be used in no more than three applications at a single plant

s ite, the information listed in paragraphs (i)(1)(i) through (i)(1)(iv) of this section can be submitted to the permitting authority for the source for approval instead of the Administrator.

(i) In these instances, use and conditions for use of the control technology can be approved by the permitting authority. The permitting authority shall follow the procedures specified in paragraphs (i)(2) through (i)(4) of this section except that, in these instances, a Federal Register notice is not required to estab lish the nominal efficiency for the different technology.

(ii) If, in reviewing the submittal, the permitting authority believes the control technology has broad applicability for use by other sources, the permitting authority shall submit the information provided in the application to the Director of the EPA Office of Air Quality Planning and Standards. The Administrator shall review the technology for broad applicability and may publish a Federal Register notice; however, this review shall not affect th e permitting authority ’ s approval of the nominal efficiency of the control technology for the specific application.Page 63 of 107

(6) If, in reviewing an application for a control technology for an emission point , the Administrator or permitting authority determines the control technology is not different in use or design from the reference control technology, the Administrator or permitting authority shall deny the application.

(j) The following procedures shall be used for calculating the efficiency (percentage of

redu ction ) of pollution prevention measures:

(1) A pollution prevention measure is any practice that meets the criteria of paragraphs (j)(1)(i) and (j)(1)(ii) of this section.

(i) A pollution prevention measure is any practice that results in a lesser quantity of organic HAP emissions per unit of product released to the atmosphere prior to out

- of

- process recycling, treatment, or control of emissions while the same product is produced.

(ii) Pollution prevention measures may include : Substitution of feedstocks th at reduce HAP emissions, alterations to the production process to reduce the volume of materials released to the environment, equipment modifications; housekeeping measures, and in

- process recycling that returns waste materials directly to production as ra w materials. Production cutbacks do not qualify as pollution prevention.

(2) The emission reduction efficiency of pollution prevention measures implemented after November 15, 1990 can be used in calculating the actual emissions from an emission point in th e debit and credit equations in paragraphs (g) and (h) of this section.

(i) For pollution prevention measures, the percentage of reduction used in the equations in paragraphs (g)(2) and (g)(3) of this section and paragraphs (h)(2) through (h)(4) of this se ction is the difference in percentage between the monthly organic HAP emissions for each emission point after the pollution prevention measure for the most recent month versus monthly emissions from the same emission point before the pollution prevention m easure, adjusted by the volume of product produced during the two monthly periods.

(ii) The following equation shall be used to calculate the percentage of reduction of a pollution prevention measure for each emission point.

Where:

Percent reduction = Efficiency of pollution prevention measure (percentage of organic HAP reduction).Page 64 of 107

E B = Monthly emissions before the pollution prevention measure, megagrams per month, determined as specified in paragraphs (j)(2)(ii)(A), (j)(2)(ii)(B), and (j)(2)(ii)(C) of this section.

E pp = Monthly emissions after the pollution prevention measure, megagrams per month, as determined for the most recent month, determined as specified in paragraphs (j)(2)(ii)(D) or (j)(2)(ii)(E) of this section

.

P B = Monthly production before the pollution prevention measure, megagrams per month, during the same period over which E B is calculated.

P pp = Monthly production after the pollution prevention me asure, megagrams per month, as

determined for the most recent month.

(A) The monthly emissions before the pollution prevention measure, E B , shall be determined in a manner consistent with the equations and procedures in paragraphs (g)(2), (g)(3), (g)(4), a nd (g)(5) of this section for miscellaneous process vents, storage vessels, gasoline loading racks, and

marine tank vessels.

(B) For wastewater, E B shall be calculated as follows:

where:

n = Number of wastewater streams.

Q Bi = Average flow rate for wastewater stream i before the pollution prevention measure, liters per minute.

H Bi = Number of hours per month that wastewater stream i was discharged before the pollut ion prevention measure, hours per month.

s = Total number of organic HAP ’ s in wastewater stream i.

Fe
m = Fraction emitted of organic HAP m in wastewater from table 7 of this subpart,

dimensionless.

HAP Bim = Average concentration of organic HAP m in wastewa ter stream i, defined and determined according to paragraph (h)(6)(ii)(A)( 2 ) of this section, before the pollution prevention measure, parts per million by weight, as measured before the implementation of the pollution measure.

(C) If the pollution prevent ion measure was implemented prior to July 14, 1994, records may be

used to determine E B

.Page 65 of 107

(D) The monthly emissions after the pollution prevention measure, E pp , may be determined during a performance test or by a design evaluation and documented engineering calculations.

Once an emissions

- to

- production ratio has been established, the ratio can be used to estimate monthly emissions from monthly production records.

(E) For wastewater , E pp shall be calculated using the following equation:

where n, Q, H, s, Fe

m , and HAP are defined and determined as described in paragraph (j)(2)(ii)(B) of this section except that Q ppi , H ppi , and HAP ppim shall be determined after the poll ution prevention measure has been implemented.

(iii) All equations, calculations, test procedures, test results, and other information used to determine the percentage of reduction achieved by a pollution prevention measure for each emission point shall be fully documented.

(iv) The same pollution prevention measure may reduce emissions from multiple emission points. In such cases, the percentage of reduction in emissions for each emission point must be

calculated.

(v) For the purposes of the equations in p aragraphs (h)(2) through (h)(6) of this section used to calculate credits for emission points controlled more stringently than the reference control technology, the nominal efficiency of a pollution prevention measure is equivalent to the percentage of red uction of the pollution prevention measure. When a pollution prevention measure is used, the owner or operator of a source is not required to apply to the Administrator for a nominal efficiency and is not subject to paragraph (i) of this section.

(k) The o wner or operator shall demonstrate that the emissions from the emission points proposed to be included in the average will not result in greater hazard or, at the option of the State or local permitting authority, greater risk to human health or the enviro nment than if the emission points were controlled according to the provisions in §§63.643 through 63.647, and §§63.650 and 63.651.

(1) This demonstration of hazard or risk equivalency shall be made to the satisfaction of the State or local permitting autho rity.

(i) The State or local permitting authority may require owners and operators to use specific methodologies and procedures for making a hazard or risk determination.

(ii) The demonstration and approval of hazard or risk equivalency may be made accordi ng to any guidance that the EPA makes available for use.Page 66 of 107

(2) Owners and operators shall provide documentation demonstrating the hazard or risk equivalency of their proposed emissions average in their Implementation Plan.

(3) An emissions averaging plan tha t does not demonstrate an equivalent or lower hazard or risk to the satisfaction of the State or local permitting authority shall not be approved. The State or local permitting authority may require such adjustments to the emissions averaging plan as are

n ecessary in order to ensure that the average will not result in greater hazard or risk to human health or the environment than would result if the emission points were controlled according to §§63.643 through 63.647, and §§63.650 and 63.651.

(4) A hazard o r risk equivalency demonstration shall:

(i) Be a quantitative, bona fide chemical hazard or risk assessment;

(ii) Account for differences in chemical hazard or risk to human health or the environment; and

(iii) Meet any requirements set by the State or loc al permitting authority for such demonstrations.

(l) For periods of excess emissions, an owner or operator may request that the provisions of paragraphs (l)(1) through (l)(4) of this section be followed instead of the procedures in paragraphs (f)(3)(i) and (f)(3)(ii) of this section.

(1) The owner or operator shall notify the Administrator of excess emissions in the Periodic Reports as required in §63.655(g)(6).

(2) The owner or operator shall demonstrate that other types of monitoring data or engineering

c alculations are appropriate to establish that the control device for the emission point was operating in such a fashion to warrant assigning full or partial credits and debits. This

demonstration shall be made to the Administrator ’ s satisfaction, and the A dministrator may establish procedures for demonstrating compliance that are acceptable.

(3) The owner or operator shall provide documentation of the period of excess emissions and the other type of monitoring data or engineering calculations to be used to demonstrate that the control device for the emission point was operating in such a fashion to warrant assigning full or partial credits and debits.

(4) The Administrator may assign full or partial credit and debits upon review of the information provided.

§ 63.653 Monitoring, recordkeeping, and implementation plan for emissions averaging.

(a) For each emission point included in an emissions average, the owner or operator shall perform testing, monitoring, recordkeeping, and reporting equivalent to that re quired for Group 1 emission points complying with §§63.643 through 63.647, and §§63.650 and 63.651. The specific requirements for miscellaneous process vents, storage vessels, wastewater, gasolinePage 67 of 107

loading racks, and marine tank vessels are identified in pa ragraphs (a)(1) through (a)(7) of this

section.

(1) The source shall implement the following testing, monitoring, recordkeeping, and reporting procedures for each miscellaneous process vent equipped with a flare, incinerator, boiler, or process heater:

(i) Conduct initial performance tests to determine the percentage of reduction as specified in §63.645 of this subpart and §63.116 of subpart G; and

(ii) Monitor the operating parameters specified in §63.644, as appropriate for the specific control

device.

(2 ) The source shall implement the following procedures for each miscellaneous process vent, equipped with a carbon adsorber, absorber, or condenser but not equipped with a control device:

(i) Determine the flow rate and organic HAP concentration using the m ethods specified in §63.115 (a)(1) and (a)(2), §63.115 (b)(1) and (b)(2), and §63.115(c)(3) of subpart G; and

(ii) Monitor the operating parameters specified in §63.114 of subpart G, as appropriate for the specific recovery device.

(3) The source shall imp lement the following procedures for each storage vessel controlled with an internal floating roof, external roof, or a closed vent system with a control device, as appropriate to the control technique:

(i) Perform the monitoring or inspection procedures in §63.646 of this subpart and §63.120 of subpart G; and

(ii) For closed vent systems with control devices, conduct an initial design evaluation as specified in §63.646 of this subpart and §63.120(d) of subpart G.

(4) For each gasoline loading rack that is c ontrolled, perform the testing and monitoring procedures specified in §§63.425 and 63.427 of subpart R of this part except §63.425(d) or §63.427(c).

(5) For each marine tank vessel that is controlled, perform the compliance, monitoring, and performance tes ting, procedures specified in §§63.563, 63.564, and 63.565 of subpart Y of this

part.

(6) The source shall implement the following procedures for wastewater emission points, as appropriate to the control techniques:

(i) For wastewater treatment processes, conduct tests as specified in §61.355 of subpart FF of part 60;Page 68 of 107

(ii) Conduct inspections and monitoring as specified in §§61.343 through 61.349 and §61.354 of 40 CFR part 61, subpart FF.

(7) If an emission point in an emissions average is controlled using a pollution prevention measure or a device or technique for which no monitoring parameters or inspection procedures are specified in §§63.643 through 63.647 and §§63.650 and 63.651, the owner or operator shall

establish a site

- specific monitoring parameter and shall submit the information specified in §63.655(h)(4) in the Implementation Plan.

(b) Records of all information required to calculate emission debits and credits and records required by §63.655 shall be retained for 5 years.

(c) Notifications of Co mpliance Status report , Periodic Reports, and other reports shall be submitted as required by §63.655.

(d) Each owner or operator of an existing source who elects to comply with §63.655(g) and (h) by using emissions averaging for any emission points shall submit an Implementation Plan.

(1) The Implementation Plan shall be submitted to the Administrator and approved prior to implementing emissions averaging. This information may be submitted in an operating permit application, in an amendment to an operating permit application, in a separate submittal, in a Notification of Compliance Status Report, in a Periodic Report or in any combination of these documents. If an owner or operator submits the information specified in paragraph (d)(2) of this

section at dif ferent times, and/or in different submittals, later submittals may refer to earlier submittals instead of duplicating the previously submitted information.

(2) The Implementation Plan shall include the information specified in paragraphs (d)(2)(i) through (d)(2)(ix) of this section for all points included in the average.

(i) The identification of all emission points in the planned emissions average and notation of whether each emission point is a Group 1 or Group 2 emission point as defined in §63.641.

(ii) The projected annual emission debits and credits for each emission point and the sum for the emission points involved in the average calculated according to §63.652. The annual projected credits must be greater than the projected debits, as required under §63.652(e)(3).

(iii) The specific control technology or pollution prevention measure that will be used for each emission point included in the average and date of application or expected date of application.

(iv) The specific identification of each emissi on point affected by a pollution prevention

measure . To be considered a pollution prevention measure, the criteria in §63.652(j)(1) must be met. If the same pollution prevention measure reduces or eliminates emissions from multiple emission points in the a verage, the owner or operator must identify each of these emission points.Page 69 of 107

(v) A statement that the compliance demonstration, monitoring, inspection, recordkeeping, and reporting provisions in paragraphs (a), (b), and (c) of this section that are applicabl e to each emission point in the emissions average will be implemented beginning on the date of compliance.

(vi) Documentation of the information listed in paragraphs (d)(2)(vi)(A) through (d)(2)(vi)(D) of this section for each emission point included in th e average.

(A) The values of the parameters used to determine whether each emission point in the emissions average is Group 1 or Group 2.

(B) The estimated values of all parameters needed for input to the emission debit and credit calculations in §63.652 ( g) and (h). These parameter values or, as appropriate, limited ranges for the parameter values, shall be specified in the source ’ s Implementation Plan as enforceable operating conditions. Changes to these parameters must be reported in the next Periodic Re port.

(C) The estimated percentage of reduction if a control technology achieving a lower percentage of reduction than the efficiency of the reference control technology, as defined in §63.641, is or will be applied to the emission point.

(D) The anticipat ed nominal efficiency if a control technology achieving a greater percentage emission reduction than the efficiency of the reference control technology is or will be applied to the emission point. The procedures in §63.652(i) shall be followed to apply for a nominal efficiency.

(vii) The information specified in §63.655(h)(4) for:

(A) Each miscellaneous process vent controlled by a pollution prevention measure or control technique for which monitoring parameters or inspection procedures are not specified in paragraphs (a)(1) or (a)(2) of this section; and

(B) Each storage vessel controlled by a pollution prevention measure or a control technique other than an internal or external floating roof or a closed vent system with a control device.

(viii) Documentati on of the information listed in paragraphs (d)(2)(viii)(A) through (d)(2)(viii)(G) of this section for each process wastewater stream included in the average.

(A) The information used to determine whether the wastewater stream is a Group 1 or Group 2

waste water stream.

(B) The estimated values of all parameters needed for input to the wastewater emission credit and debit calculations in §63.652(h)(6).

(C) The estimated percentage of reduction if the wastewater stream is or will be controlled using

a treatme nt process or series of treatment processes that achieves an emission reduction less than or equal to the emission reduction specified in table 7 of this subpart.Page 70 of 107

(D) The estimated percentage of reduction if a control technology achieving less than or equa l to 95 percent emission reduction is or will be applied to the vapor stream(s) vented and collected from the treatment processes.

(E) The estimated percentage of reduction if a pollution prevention measure is or will be applied.

(F) The anticipated nomina l efficiency if the owner or operator plans to apply for a nominal efficiency under §63.652(i). A nominal efficiency shall be applied for if:

( 1 ) A control technology is or will be applied to the wastewater stream and achieves an emission reduction greater than the emission reduction specified in table 7 of this subpart; or

( 2 ) A control technology achieving greater than 95 percent emission reduction is or will be applied to the vapor stream(s) vented and collected from the treatment processes.

(G) For each pollution prevention measure, treatment process, or control device used to reduce air emissions of organic HAP from wastewater and for which no monitoring parameters or inspection procedures are specified in §63.647, the information specified in §63.655(h )(4) shall be included in the Implementation Plan.

(ix) Documentation required in §63.652(k) demonstrating the hazard or risk equivalency of the proposed emissions average.

(3) The Administrator shall determine within 120 calendar days whether the Implemen tation Plan submitted presents sufficient information. The Administrator shall either approve the Implementation Plan, request changes, or request that the owner or operator submit additional

information. Once the Administrator receives sufficient informat ion, the Administrator shall approve, disapprove, or request changes to the plan within 120 calendar days.

§ 63.654 Heat exchange systems.

(a) Except as specified in paragraph (b) of this section, t T he owner or operator of a heat exchange system that mee ts the criteria in §63.640(c)(8) must comply with the requirements of §65.610 as specified in paragraphs ( b c ) through ( e g ) of this section.

(b) For purposes of compliance with §65.610 , the following terms have the meanings specified in paragraphs (b)(1) an d (2).

(1) “ R egulated material” means any “hazardous air pollutant” as defined by §63.641 of this subpart

.

(2) “ I n regulated material service” means “in organic hazardous air pollutant service” as defined by §63.641 of this subpart.

( c ) For a heat exchang e system at an existing source , the owner or operator must comply with the monitoring frequency and leak definition as defined in paragraph (c)(1) of thisPage 71 of 107

section or comply with the monitoring frequency and leak definition as defined in paragraph (c)(2) of this section. The owner or operator of a n affected heat exchange system may choose to comply with paragraph (c)(1) for some heat exchange systems at the petroleum refinery and comply with paragraph (c)(2) for other heat exchange systems. However, for each affected heat exchange system, the owner or operator of a n affected heat exchange system must elect one monitoring alternative that will apply at all times. If the owner or operator intends to change the monitoring alternative that applies to a heat

excha nge system, the owner or operator must notify the Administrator 30 days in advance of such a change. All “leaks” identified prior to changing monitoring alternatives must be repaired.

(1) Monitor monthly using a leak action level defined as either a total strippable hydrocarbon concentration (as methane) in the stripping gas of 6.2 parts per million by

volume or a total strippable hydrocarbon concentration in the cooling water of 80 parts per billion by weight

.

(2) Monitor quarterly using a leak action leve l defined as either a total strippable hydrocarbon concentration (as methane) in the stripping gas of 3

. 1 parts per million by

volume or a total strippable hydrocarbon concentration in the cooling water of 40 parts per billion by weight

.

(d) For a heat exc hange system at a new source, the owner or operator must monitor monthly using a leak action level defined as either a total strippable hydrocarbon concentration (as methane) in the stripping gas of 3

. 1 parts per million by volume or a total strippable hyd rocarbon concentration in the cooling water of 40 parts per billion by weight

.

( e ) For the purposes of §65.610(f), the delay of repair action level is a total strippable hydrocarbon concentration (as methane) in the stripping gas of 62 parts per million by

volume or a total strippable hydrocarbon concentration in the cooling water of 800 parts per billion by weight

.

(b) A heat exchange system is exempt from the requirements in paragraphs (c) through (g) of this section if it meets any one of the criteria in paragraphs (b)(1) through (2) of this section.

(1) All heat exchangers that are in organic HAP service within the heat exchange system that

either:

(i) Operate with the minimum pressure on the cooling water side at least 35 kilopascals greater

than the ma ximum pressure on the process side; or

(ii) Employ an intervening cooling fluid, containing less than 5 percent by weight of total HAP listed in Table 1 to this subpart, between the process and the cooling water. This intervening

fluid must serve to isolat e the cooling water from the process fluid and must not be sent through a cooling tower or discharged. For purposes of this section, discharge does not include emptying for maintenance purposes.Page 72 of 107

(2) The heat exchange system cools process fluids that contai n less than 5 percent by weight of total HAP listed in Table 1 to this subpart (i.e., the heat exchange system does not contain any heat exchangers that are in organic HAP service as defined in this subpart).

(c) The owner or operator must perform monthly monitoring to identify leaks of total strippable volatile organic compound (VOC) from each heat exchange system subject to the requirements of this subpart according to the procedures in paragraphs (c)(1) and (2) of this section.

(1) Collect and analyze a sample from each cooling tower return line prior to exposure to air for each heat exchange system in organic HAP service or from each heat exchanger exit line for each heat exchanger or group of heat exchangers in organic HAP service within that heat

excha nge system to determine the total strippable VOC concentration (as methane) from the air stripping testing system using “Air Stripping Method (Modified El Paso Method) for Determination of Volatile Organic Compound Emissions from Water Sources” Revision Nu mber 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). The owner or operator of a once

- through heat exc hange system may elect to also monitor monthly (in addition to monitoring each heat exchanger exit line) the fresh water feed line prior to any heat exchanger to determine the total strippable VOC concentration (as methane) prior to the heat exchange syste m using the Modified El Paso

Method.

(2) For a heat exchange system at an existing source, a leak is a total strippable VOC concentration (as methane) in the stripping gas of 6.2 ppmv or greater. For a heat exchange system at a new source, a leak is a tota l strippable VOC concentration (as methane) in the stripping gas of 3.1 ppmv or greater.

(d) If a leak is detected , the owner or operator must repair the leak 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, except as specified in paragraphs (e) and (f) of this section. Actions that can be taken to achieve repair include but are not limited to:

(1) Physical modifications to the leaking heat exchanger, such as welding the leak or replacing a tube;

(2) Blocking the leaking tube within the heat exchanger;

(3) Changing the pressure so that water flows into the process fluid;

(4) Replacing the heat exchanger or heat exchanger bundle; or

(5) Isolating, bypassing, or otherwise removing the leaking heat exchanger from service until it is otherwise repaired.

(e) If the owner or operator detects a leak when monitoring a cooling tower return line under paragraph (c)(1) of this section, the owner or operator may conduct additional monitoring toPage 73 of 107

identify leaks of total strippable VOC emissions using Modified El Paso Method from each heat exchanger or group of heat exchangers in organic HAP service associated with the heat exchange system for which the leak was detected. I f the additional monitoring shows that the total strippable VOC concentration in the stripped air at the heat exchanger exit line for each heat exchanger in organic HAP service is less than 6.2 ppmv for existing sources or less than 3.1 ppmv for new source s, the heat exchange system is excluded from repair requirements in paragraph (d) of this section.

(f) The owner or operator may delay the repair of a leaking heat exchanger when one of the conditions in paragraphs (f)(1) and (2) of this section is met. Th e owner or operator must determine if a delay of repair is necessary as soon as practicable, but no later than 45 days after first identifying the leak.

(1) If the repair is technically infeasible without a shutdown and the total strippable VOC

concentrati on (as methane) is initially and remains less than 62 ppmv for all monthly monitoring periods during the delay of repair, the owner or operator may delay repair until the next scheduled shutdown of the heat exchange system. If, during subsequent monthly mo nitoring, the total strippable VOC concentration (as methane) is 62 ppmv or greater, the owner or operator must repair the leak within 30 days of the monitoring event in which the leak was equal to or exceeded 62 ppmv total strippable VOC (as methane), exc ept as provided in paragraph (f)(3) of

this section.

(2) If the necessary equipment, parts, or personnel are not available and the total strippable VOC

concentration (as methane) is initially and remains less than 62 ppmv for all monthly monitoring periods during the delay of repair, the owner or operator may delay the repair for a maximum of 120 calendar days. The owner or operator must demonstrate that the necessary equipment, parts, or personnel were not available. If, during subsequent monthly monitorin g, the total strippable VOC concentration (as methane) is 62 ppmv or greater, the owner or operator must repair the leak within 30 days of the monitoring event in which the leak was equal to or exceeded 62 ppmv total strippable VOC (as methane).

(g) To del ay the repair under paragraph (f) of this section, the owner or operator must record the information in paragraphs (g)(1) through (g)(4) of this section.

(1) The reason(s) for delaying repair.

(2) A schedule for completing the repair as soon as practical.

(3) The date and concentration of the leak as first identified and the results of all subsequent monthly monitoring events during the delay of repair.

(4) An estimate of the potential emissions from the leaking heat exchange system or heat exchanger follow ing the procedures in paragraphs (g)(4)(i) and (g)(4)(ii) of this section.

(i) Determine the total strippable VOC concentration in the cooling water, in parts per million by weight (ppmw), using equation 7

– 1 from “Air Stripping Method (Modified El Paso Met hod) forPage 74 of 107

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), based on the total strippable concentration in the stripped air, ppmv, from monitoring.

(ii) Calculate the VOC emissions for the leaking heat exchange system or heat exchanger by multiplying the VOC concentratio n in the cooling water, ppmw, by the flow rate of the cooling water from the leaking tower or heat exchanger and by the expected duration of the delay.

§ 63.655 Reporting and recordkeeping requirements.

(a) Each owner or operator subject to the wastewate r provisions in §63.647 shall comply with the recordkeeping and reporting provisions in §§61.356 and 61.357 of 40 CFR part 61, subpart FF unless they are complying with the wastewater provisions specified in paragraph (o)(2)(ii) of §63.640. There are no ad ditional reporting and recordkeeping requirements for wastewater under this subpart unless a wastewater stream is included in an emissions average. Recordkeeping and reporting for emissions averages are specified in §63.653 and in paragraphs (f)(5) and (g) (8) of

this section.

(b) Each owner or operator subject to the gasoline loading rack provisions in §63.650 shall comply with the recordkeeping and reporting provisions in §63.428 (b) and (c), (g)(1), (h)(1) through (h)(3), and (k) of subpart R. These requi rements are summarized in table 4 of this subpart. There are no additional reporting and recordkeeping requirements for gasoline loading racks under this subpart unless a loading rack is included in an emissions average. Recordkeeping and reporting for emi ssions averages are specified in §63.653 and in paragraphs (f)(5) and (g)(8) of this section.

(c) Each owner or operator subject to the marine tank vessel loading operation standards in §63.651 shall comply with the recordkeeping and reporting provisions i n §63.567(a) and §63.567(c) through (k) of subpart Y. These requirements are summarized in table 5 of this subpart. There are no additional reporting and recordkeeping requirements for marine tank vessel loading operations under this subpart unless marine tank vessel loading operations are included in an emissions average. Recordkeeping and reporting for emissions averages are specified in §63.653 and in paragraphs (f)(5) and (g)(8) of this section.

(d) Each owner or operator subject to the equipment leaks standards in §63.648 shall comply with the recordkeeping and reporting provisions in paragraphs (d)(1) through (d)(6) of this

section.

(1) Sections 60.486 and 60.487 of subpart VV of part 60 except as specified in paragraph (d)(1)(i) of this section; or §§ 63.181 and 63.182 of subpart H of this part except for §§63.182(b), (c)(2), and (c)(4).

(i) The signature of the owner or operator (or designate) whose decision it was that a repair could not be effected without a process shutdown is not required to be rec orded. Instead, the name ofPage 75 of 107

the person whose decision it was that a repair could not be effected without a process shutdown shall be recorded and retained for 2 years.

(ii) [Reserved]

(2) The Notification of Compliance Status report required by §63.182(c) of subpart H and the initial semiannual report required by §60.487(b) of 40 CFR part 60, subpart VV shall be submitted within 150 days of the compliance date specified in §63.640(h); the requirements of subpart H of this part are summarized in table 3 of t his subpart.

(3) An owner or operator who determines that a compressor qualifies for the hydrogen service exemption in §63.648 shall also keep a record of the demonstration required by §63.648.

(4) An owner or operator must keep a list of identification nu mbers for valves that are designated as leakless per §63.648(c)(10).

(5) An owner or operator must identify, either by list or location (area or refining process unit), equipment in organic HAP service less than 300 hours per year within refining process u nits subject to this subpart.

(6) An owner or operator must keep a list of reciprocating pumps and compressors determined to be exempt from seal requirements as per §§63.648 (f) and (i).

(e) Each owner or operator of a source subject to this subpart shall submit the reports listed in paragraphs (e)(1) through (e)(3) of this section except as provided in paragraph (h)(5) of this section, and shall keep records as described in paragraph (i) of this section.

(1) A Notification of Compliance Status report as de scribed in paragraph (f) of this section;

(2) Periodic Reports as described in paragraph (g) of this section; and

(3) Other reports as described in paragraph (h) of this section.

(f) Each owner or operator of a source subject to this subpart shall submit a Notification of Compliance Status report within 150 days after the compliance dates specified in §63.640(h) with the exception of Notification of Compliance Status reports submitted to comply with §63.640(l)(3) and for storage vessels subject to the compl iance schedule specified in §63.640(h)(4). Notification of Compliance Status reports required by §63.640(l)(3) and for storage vessels subject to the compliance dates specified in §63.640(h)(4) shall be submitted according to paragraph (f)(6) of this secti on. This information may be submitted in an operating permit application, in an amendment to an operating permit application, in a separate submittal, or in any combination of the three. If the required information has been submitted before the date

150 da ys after the compliance date specified in §63.640(h), a separate Notification of Compliance Status report is not required within 150 days after the compliance dates specified in §63.640(h). If an owner or operator submits the information specified in parag raphs (f)(1) through (f)(5) of this section at different times, and/or in different submittals, later submittalsPage 76 of 107

may refer to earlier submittals instead of duplicating and resubmitting the previously submitted information. Each owner or operator of a gasol ine loading rack classified under Standard Industrial Classification Code 2911 located within a contiguous area and under common control with a petroleum refinery subject to the standards of this subpart shall submit the Notification of Compliance Status r eport required by subpart R of this part within 150 days after the compliance dates specified in §63.640(h) of this subpart.

(1) The Notification of Compliance Status report shall include the information specified in paragraphs (f)(1)(i) through (f)(1)(vi) of this section.

(i) For storage vessels, this report shall include the information specified in paragraphs (f)(1)(i)(A) through (f)(1)(i)(D) of this section.

(A) Identification of each storage vessel subject to this subpart, and for each Group 1 storage vessel subject to this subpart, the information specified in paragraphs (f)(1)(i)(A)( 1 ) through (f)(1)(i)(A)( 3 ) of this section. This information is to be revised each time a Notification of Compliance Status report is submitted for a storage vessel subjec t to the compliance schedule specified in §63.640(h)(4) or to comply with §63.640(l)(3).

( 1 ) For each Group 1 storage vessel complying with §63.646 that is not included in an emissions average, the method of compliance (i.e., internal floating roof, extern al floating roof, or closed vent system and control device).

( 2 ) For storage vessels subject to the compliance schedule specified in §63.640(h)(4) that are not complying with §63.646, the anticipated compliance date.

( 3 ) For storage vessels subject to the compliance schedule specified in §63.640(h)(4) that are complying with §63.646 and the Group 1 storage vessels described in §63.640(l), the actual compliance date.

(B) If a closed vent system and a control device other than a flare is used to comply with § 63.646 the owner or operator shall submit:

( 1 ) A description of the parameter or parameters to be monitored to ensure that the control device is being properly operated and maintained, an explanation of the criteria used for selection of that parameter (or parameters), and the frequency with which monitoring will be performed; and

either

( 2 ) The design evaluation documentation specified in §63.120(d)(1)(i) of subpart G, if the owner or operator elects to prepare a design evaluation; or

( 3 ) If the owner or o perator elects to submit the results of a performance test, identification of the storage vessel and control device for which the performance test will be submitted, and identification of the emission point(s) that share the control device with the storage vessel and for which the performance test will be conducted.Page 77 of 107

(C) If a closed vent system and control device other than a flare is used, the owner or operator

shall submit:

( 1 ) The operating range for each monitoring parameter. The specified operating rang e shall represent the conditions for which the control device is being properly operated and maintained.

( 2 ) If a performance test is conducted instead of a design evaluation, results of the performance test demonstrating that the control device achieves g reater than or equal to the required control efficiency. A performance test conducted prior to the compliance date of this subpart can be used to comply with this requirement, provided that the test was conducted using EPA methods and

that the test conditi ons are representative of current operating practices.

(D) If a closed vent system and a flare is used, the owner or operator shall submit:

( 1 ) Flare design (e.g., steam

- assisted, air

- assisted, or nonassisted);

( 2 ) All visible emission readings, heat conte nt determinations, flow rate measurements, and exit velocity determinations made during the compliance determination required by §63.120(e) of subpart G of this part; and

( 3 ) All periods during the compliance determination when the pilot flame is absent.

( ii) For miscellaneous process vents, identification of each miscellaneous process vent subject to this subpart, whether the process vent is Group 1 or Group 2, and the method of compliance for each Group 1 miscellaneous process vent that is not included in an emissions average (e.g., use of a flare or other control device meeting the requirements of §63.643(a)).

(iii) For miscellaneous process vents controlled by control devices required to be tested under §63.645 of this subpart and §63.116(c) of subpart G of this part, performance test results including the information in paragraphs (f)(1)(iii)(A) and (B) of this section. Results of a performance test conducted prior to the compliance date of this subpart can be used provided that

the test was conducted us ing the methods specified in §63.645 and that the test conditions are representative of current operating conditions.

(A) The percentage of reduction of organic HAP ’ s or TOC, or the outlet concentration of organic

HAP ’ s or TOC (parts per million by volume on a dry basis corrected to 3 percent oxygen), determined as specified in §63.116(c) of subpart G of this part; and

(B) The value of the monitored parameters specified in table 10 of this subpart, or a site

- specific parameter approved by the permitting aut hority, averaged over the full period of the performance

test,

(iv) For miscellaneous process vents controlled by flares, performance test results including the information in paragraphs (f)(1)(iv)(A) and (B) of this section;Page 78 of 107

(A) All visible emission readi ngs, heat content determinations, flow rate measurements, and exit velocity determinations made during the compliance determination required by §63.645 of this subpart and §63.116(a) of subpart G of this part, and

(B) A statement of whether a flame was pre sent at the pilot light over the full period of the compliance determination.

(v) For equipment leaks complying with §63.648(c) (i.e., complying with the requirements of subpart H of this part), the Notification of Compliance Report Status report informati on required by §63.182(c) of subpart H and whether the percentage of leaking valves will be reported on a process unit basis or a sourcewide basis.

(vi) For each heat exchange system, identification of the heat exchange systems that are subject to the requ irements of this subpart. For heat exchange systems at existing sources, the owner or operator shall indicate whether monitoring will be conducted as specified in §6 3 .6 54(c)(1) or §6 3 .6 54(c)(2).

(2) If initial performance tests are required by §§63.643 thr ough 63.653 of this subpart, the Notification of Compliance Status report shall include one complete test report for each test method used for a particular source.

(i) For additional tests performed using the same method, the results specified in paragraph (f)(1) of this section shall be submitted, but a complete test report is not required.

(ii) A complete test report shall include a sampling site description, description of sampling and analysis procedures and any modifications to standard procedures, qua lity assurance procedures, record of operating conditions during the test, record of preparation of standards, record of calibrations, raw data sheets for field sampling, raw data sheets for field and laboratory analyses, documentation of calculations, and any other information required by the test method.

(iii) Performance tests are required only if specified by §§63.643 through 63.653 of this subpart. Initial performance tests are required for some kinds of emission points and controls. Periodic testing o f the same emission point is not required.

(3) For each monitored parameter for which a range is required to be established under §63.120(d) of subpart G of this part for storage vessels or §63.644 for miscellaneous process vents, the Notification of Compl iance Status report shall include the information in paragraphs (f)(3)(i) through (f)(3)(iii) of this section.

(i) The specific range of the monitored parameter(s) for each emission point;

(ii) The rationale for the specific range for each parameter for ea ch emission point, including any data and calculations used to develop the range and a description of why the range ensures compliance with the emission standard.Page 79 of 107

(A) If a performance test is required by this subpart for a control device, the range shall b e based

on the parameter values measured during the performance test supplemented by engineering

assessments and manufacturer ’ s recommendations. Performance testing is not required to be conducted over the entire range of permitted parameter values.

(B) If a performance test is not required by this subpart for a control device, the range may be based solely on engineering assessments and manufacturers ’ recommendations.

(iii) A definition of the source ’ s operating day for purposes of determining daily averag e values of monitored parameters. The definition shall specify the times at which an operating day begins

and ends.

(4) Results of any continuous monitoring system performance evaluations shall be included in the Notification of Compliance Status report.

( 5) For emission points included in an emissions average, the Notification of Compliance Status report shall include the values of the parameters needed for input to the emission credit and debit equations in §63.652(g) and (h), calculated or measured accor ding to the procedures in §63.652(g) and (h), and the resulting credits and debits for the first quarter of the year. The first quarter begins on the compliance date specified in §63.640.

(6) Notification of Compliance Status reports required by § 63 .640(l) (3) and for storage vessels subject to the compliance dates specified in §63.640(h)(4) shall be submitted no later than 60 days after the end of the 6

- month period during which the change or addition was made that resulted in the Group 1 emission point or the existing Group 1 storage vessel was brought into compliance, and may be combined with the periodic report. Six

- month periods shall be the same

6

- month periods specified in paragraph (g) of this section. The Notification of Compliance Status report shal l include the information specified in paragraphs (f)(1) through (f)(5) of this section. This information may be submitted in an operating permit application, in an amendment to an operating permit application, in a separate submittal, as part of the perio dic report, or in any combination of these four. If the required information has been submitted before the date 60 days

after the end of the 6

- month period in which the addition of the Group 1 emission point took place, a separate Notification of Complianc e Status report is not required within 60 days after the

end of the 6

- month period. If an owner or operator submits the information specified in paragraphs (f)(1) through (f)(5) of this section at different times, and/or in different submittals,

later subm ittals may refer to earlier submittals instead of duplicating and resubmitting the previously submitted information.

(g) The owner or operator of a source subject to this subpart shall submit Periodic Reports no later than 60 days after the end of each 6

- m onth period when any of the compliance exceptions specified in paragraphs (g)(1) through (6) of this section or paragraph (g)(9) of this section occur.

The first 6

- month period shall begin on the date the Notification of Compliance Status report is require d to be submitted. A Periodic Report is not required if none of the compliance exceptions identified in paragraph (g)(1) through (6) of this section or paragraph (g)(9) of this section occurred during the 6

- month period unless emissions averaging is utiliz ed. Quarterly reports must be submitted for emission points included in emission averages, as provided in paragraphPage 80 of 107

(g)(8) of this section. An owner or operator may submit reports required by other regulations in place of or as part of the Periodic Report required by this paragraph if the reports contain the information required by paragraphs (g)(1) through (9) of this section.

(1) For storage vessels, Periodic Reports shall include the information specified for Periodic Reports in paragraph (g)(2) through (g)(5) of this section except that information related to gaskets, slotted membranes, and sleeve seals is not required for storage vessels that are part of an existing source.

(2) An owner or operator who elects to comply with §63.646 by using a fixed roof and an internal floating roof or by using an external floating roof converted to an internal floating roof shall submit the results of each inspection conducted in accordance with §63.120(a) of subpart G of this part in which a failure is detected in the control equipment.

(i) For vessels for which annual inspections are required under §63.120(a)(2)(i) or (a)(3)(ii) of subpart G of this part, the specifications and requirements listed in paragraphs (g)(2)(i)(A) through (g)(2)(i)(C) of this section apply.

( A) A failure is defined as any time in which the internal floating roof is not resting on the surface of the liquid inside the storage vessel and is not resting on the leg supports; or there is liquid on the floating roof; or the seal is detached from the internal floating roof; or there are holes, tears, or other openings in the seal or seal fabric; or there are visible gaps between the seal and the wall of the storage vessel.

(B) Except as provided in paragraph (g)(2)(i)(C) of this section, each Periodic Report shall include the date of the inspection, identification of each storage vessel in which a failure was detected, and a description of the failure. The Periodic Report shall also describe the nature of and date the repair was made or the date the sto rage vessel was emptied.

(C) If an extension is utilized in accordance with §63.120(a)(4) of subpart G of this part, the owner or operator shall, in the next Periodic Report, identify the vessel; include the documentation specified in §63.120(a)(4) of subp art G of this part; and describe the date the storage vessel was emptied and the nature of and date the repair was made.

(ii) For vessels for which inspections are required under §63.120(a)(2)(ii), (a)(3)(i), or (a)(3)(iii) of subpart G of this part (i.e., internal inspections), the specifications and requirements listed in paragraphs (g)(2)(ii)(A) and (g)(2)(ii)(B) of this section apply.

(A) A failure is defined as any time in which the internal floating roof has defects; or the primary seal has holes, tea rs, or other openings in the seal or the seal fabric; or the secondary seal (if one has been installed) has holes, tears, or other openings in the seal or the seal fabric; or, for a storage vessel that is part of a new source, the gaskets no longer close o ff the liquid surface from the atmosphere; or, for a storage vessel that is part of a new source, the slotted membrane has more than a 10 percent open area.Page 81 of 107

(B) Each Periodic Report shall include the date of the inspection, identification of each storage

v essel in which a failure was detected, and a description of the failure. The Periodic Report shall also describe the nature of and date the repair was made.

(3) An owner or operator who elects to comply with §63.646 by using an external floating roof

shall meet the periodic reporting requirements specified in paragraphs (g)(3)(i) through (g)(3)(iii)

of this section.

(i) The owner or operator shall submit, as part of the Periodic Report, documentation of the

results of each seal gap measurement made in accor dance with §63.120(b) of subpart G of this part in which the seal and seal gap requirements of §63.120(b)(3), (b)(4), (b)(5), or (b)(6) of subpart G of this part are not met. This documentation shall include the information specified in paragraphs (g)(3)(i )(A) through (g)(3)(i)(D) of this section.

(A) The date of the seal gap measurement.

(B) The raw data obtained in the seal gap measurement and the calculations described in §63.120(b)(3) and (b)(4) of subpart G of this part.

(C) A description of any seal c ondition specified in §63.120(b)(5) or (b)(6) of subpart G of this part that is not met.

(D) A description of the nature of and date the repair was made, or the date the storage vessel was emptied.

(ii) If an extension is utilized in accordance with §63.12 0(b)(7)(ii) or (b)(8) of subpart G of this part, the owner or operator shall, in the next Periodic Report, identify the vessel; include the documentation specified in §63.120(b)(7)(ii) or (b)(8) of subpart G of this part, as applicable;

and describe the da te the vessel was emptied and the nature of and date the repair was made.

(iii) The owner or operator shall submit, as part of the Periodic Report, documentation of any failures that are identified during visual inspections required by §63.120(b)(10) of su bpart G of this part. This documentation shall meet the specifications and requirements in paragraphs (g)(3)(iii)(A) and (g)(3)(iii)(B) of this section.

(A) A failure is defined as any time in which the external floating roof has defects; or the primary se al has holes or other openings in the seal or the seal fabric; or the secondary seal has holes, tears, or other openings in the seal or the seal fabric; or, for a storage vessel that is part of a new source, the gaskets no longer close off the liquid surfa ce from the atmosphere; or, for a storage vessel that is part of a new source, the slotted membrane has more than 10 percent open

area.

(B) Each Periodic Report shall include the date of the inspection, identification of each storage

vessel in which a fail ure was detected, and a description of the failure. The Periodic Report shall also describe the nature of and date the repair was made.Page 82 of 107

(4) An owner or operator who elects to comply with §63.646 by using an external floating roof

converted to an internal f loating roof shall comply with the periodic reporting requirements of paragraph (g)(2) of this section.

(5) An owner or operator who elects to comply with §63.646 by installing a closed vent system and control device shall submit, as part of the next Perio dic Report, the information specified in paragraphs (g)(5)(i) through (g)(5)(iii) of this section.

(i) The Periodic Report shall include the information specified in paragraphs (g)(5)(i)(A) and (g)(5)(i)(B) of this section for those planned routine mainten ance operations that would require the control device not to meet the requirements of §63.119(e)(1) or (e)(2) of subpart G of this part, as applicable.

(A) A description of the planned routine maintenance that is anticipated to be performed for the

control device during the next 6 months. This description shall include the type of maintenance necessary, planned frequency of maintenance, and lengths of maintenance periods.

(B) A description of the planned routine maintenance that was performed for the contro l device during the previous 6 months. This description shall include the type of maintenance performed and the total number of hours during those 6 months that the control device did not meet the requirements of §63.119 (e)(1) or (e)(2) of subpart G of th is part, as applicable, due to planned

routine maintenance.

(ii) If a control device other than a flare is used, the Periodic Report shall describe each occurrence when the monitored parameters were outside of the parameter ranges documented in

the Notific ation of Compliance Status report. The description shall include: Identification of the control device for which the measured parameters were outside of the established ranges, and causes for the measured parameters to be outside of the established ranges.

(iii) If a flare is used, the Periodic Report shall describe each occurrence when the flare does not meet the general control device requirements specified in §63.11(b) of subpart A of this part and

shall include: Identification of the flare that does not meet the general requirements specified in §63.11(b) of subpart A of this part, and reasons the flare did not meet the general requirements specified in §63.11(b) of subpart A of this part.

(6) For miscellaneous process vents for which continuous paramete r monitors are required by this subpart, periods of excess emissions shall be identified in the Periodic Reports and shall be used to determine compliance with the emission standards.

(i) Period of excess emission means any of the following conditions:

(A) An operating day when the daily average value of a monitored parameter, except presence of a flare pilot flame, is outside the range specified in the Notification of Compliance Status report. Monitoring data recorded during periods of monitoring system br eakdown, repairs, calibration checks and zero (low

- level) and high

- level adjustments shall not be used in computing daily average values of monitored parameters.Page 83 of 107

(B) An operating day when all pilot flames of a flare are absent.

(C) An operating day when mo nitoring data required to be recorded in paragraphs (i)(3) (i) and (ii) of this section are available for less than 75 percent of the operating hours.

(D) For data compression systems approved under paragraph (h)(5)(iii) of this section, an operating day w hen the monitor operated for less than 75 percent of the operating hours or a day when less than 18 monitoring values were recorded.

(ii) For miscellaneous process vents, excess emissions shall be reported for the operating parameters specified in table 10 of this subpart unless other site

- specific parameter(s) have been approved by the operating permit authority.

(iii) Periods of startup and shutdown that meet the definition of §63.641, and malfunction that meet the definition in §63.2 and periods of perfo rmance testing and monitoring system calibration shall not be considered periods of excess emissions. Malfunctions may include process unit, control device, or monitoring system malfunctions.

(7) If a performance test for determination of compliance for a new emission point subject to this subpart or for an emission point that has changed from Group 2 to Group 1 is conducted during the period covered by a Periodic Report, the results of the performance test shall be included in the Periodic Report.

(i) Resu lts of the performance test shall include the percentage of emissions reduction or outlet pollutant concentration reduction (whichever is needed to determine compliance) and the values of the monitored operating parameters.

(ii) The complete test report sh all be maintained onsite.

(8) The owner or operator of a source shall submit quarterly reports for all emission points included in an emissions average.

(i) The quarterly reports shall be submitted no later than 60 calendar days after the end of each

quart er. The first report shall be submitted with the Notification of Compliance Status report no later than 150 days after the compliance date specified in §63.640.

(ii) The quarterly reports shall include:

(A) The information specified in this paragraph and i n paragraphs (g)(2) through (g)(7) of this section for all storage vessels and miscellaneous process vents included in an emissions average;

(B) The information required to be reported by §63.428 (h)(1), (h)(2), and (h)(3) for each gasoline loading rack in cluded in an emissions average, unless this information has already been submitted in a separate report;Page 84 of 107

(C) The information required to be reported by §63.567(e)(4) and (j)(3) of subpart Y for each marine tank vessel loading operation included in an emiss ions average, unless the information has already been submitted in a separate report;

(D) Any information pertaining to each wastewater stream included in an emissions average that the source is required to report under the Implementation Plan for the sour ce;

(E) The credits and debits calculated each month during the quarter;

(F) A demonstration that debits calculated for the quarter are not more than 1.30 times the credits calculated for the quarter, as required under §§63.652(e)(4);

(G) The values of any inputs to the credit and debit equations in §63.652 (g) and (h) that change from month to month during the quarter or that have changed since the previous quarter; and

(H) Any other information the source is required to report under the Implementation Pla n for the

source.

(iii) Every fourth quarterly report shall include the following:

(A) A demonstration that annual credits are greater than or equal to annual debits as required by §63.652(e)(3); and

(B) A certification of compliance with all the emissions averaging provisions in §63.652 of this subpart.

(9) For heat exchange systems, Periodic Reports must include the following information specified in §65.620. :

(i) The number of heat exchange systems in HAP service.

(ii) The number of heat exchange systems in HAP service found to be leaking.

(iii) A summary of the monitoring data that indicate a leak, including the number of leaks determined to be equal to or greater than the leak definitions specified in §63.654(c)(2);

(iv) If applicable, the date a leak w as identified, the date the source of the leak was identified,

and the date of repair;

(v) If applicable, a summary of each delayed repair, including the original date and reason for the delay and the date of repair, if repaired during the reporting period ; and

(vi) If applicable, an estimate of VOC emissions for each delayed repair over the reporting period.

(h) Other reports shall be submitted as specified in subpart A of this part and as follows:Page 85 of 107

(1) Reports of startup, shutdown, and malfunction required by §63.10(d)(5). Records and reports of startup, shutdown, and malfunction are not required if they pertain solely to Group 2 emission points, as defined in §63.641, that are not included in an emissions average. For purposes of this paragraph, startup an d shutdown shall have the meaning defined in §63.641, and malfunction shall have the meaning defined in §63.2; and

(2) For storage vessels, notifications of inspections as specified in paragraphs (h)(2)(i) and (h)(2)(ii) of this section;

(i) In order to af ford the Administrator the opportunity to have an observer present , the owner or operator shall notify the Administrator of the refilling of each Group 1 storage vessel that has been emptied and degassed.

(A) Except as provided in paragraphs (h)(2)(i) (B) and (C) of this section, the owner or operator

shall notify the Administrator in writing at least 30 calendar days prior to filling or refilling of each storage vessel with organic HAP ’ s to afford the Administrator the opportunity to inspect the

storage ve ssel prior to refilling.

(B) Except as provided in paragraph (h)(2)(i)(C) of this section, if the internal inspection required by §§63.120(a)(2), 63.120(a)(3), or 63.120(b)(10) of subpart G of this part is not planned and the owner or operator could not ha ve known about the inspection 30 calendar days in advance of refilling the vessel with organic HAP ’ s, the owner or operator shall notify the Administrator at least 7 calendar days prior to refilling of the storage vessel. Notification may be made by teleph one and immediately followed by written documentation demonstrating why the inspection was unplanned. This notification, including the written documentation, may also be made in writing and sent so that it is received by the Administrator at least 7 calend ar days prior to the refilling.

(C) The State or local permitting authority can waive the notification requirements of paragraphs (h)(2)(i)(A) and/or (h)(2)(i)(B) of this section for all or some storage vessels at petroleum refineries subject to this subpa rt. The State or local permitting authority may also grant permission to refill storage vessels sooner than 30 days after submitting the notification required by paragraph (h)(2)(i)(A) of this section, or sooner than 7 days after submitting the notificatio n required by paragraph (h)(2)(i)(B) of this section for all storage vessels, or for individual storage

vessels on a case

- by

- case basis.

(ii) In order to afford the Administrator the opportunity to have an observer present, the owner or operator of a stora ge vessel equipped with an external floating roof shall notify the Administrator of any seal gap measurements. The notification shall be made in writing at least 30 calendar days in advance of any gap measurements required by §63.120 (b)(1) or (b)(2) of su bpart G of this part. The State or local permitting authority can waive this notification requirement for all or some storage vessels subject to the rule or can allow less than 30 calendar days ’ notice.

(3) For owners or operators of sources required to re quest approval for a nominal control efficiency for use in calculating credits for an emissions average, the information specified in §63.652(h).Page 86 of 107

(4) The owner or operator who requests approval to monitor a different parameter than those listed in §63.644 for miscellaneous process vents or who is required by §63.653(a)(8) to establish

a site

- specific monitoring parameter for a point in an emissions average shall submit the information specified in paragraphs (h)(4)(i) through (h)(4)(iii) of this section. Fo r new or reconstructed sources, the information shall be submitted with the application for approval of construction or reconstruction required by §63.5(d) of subpart A and for existing sources, and the

information shall be submitted no later than 18 month s prior to the compliance date. The information may be submitted in an operating permit application, in an amendment to an operating permit application, or in a separate submittal.

(i) A description of the parameter(s) to be monitored to determine whether excess emissions occur and an explanation of the criteria used to select the parameter(s).

(ii) A description of the methods and procedures that will be used to demonstrate that the parameter can be used to determine excess emissions and the schedule for t his demonstration. The owner or operator must certify that they will establish a range for the monitored parameter as part of the Notification of Compliance Status report required in paragraphs (e) and (f) of this

section.

(iii) The frequency and content o f monitoring, recording, and reporting if: monitoring and recording are not continuous; or if periods of excess emissions, as defined in paragraph (g)(6) of this section, will not be identified in Periodic Reports required under paragraphs (e) and (g) of

t his section. The rationale for the proposed monitoring, recording, and reporting system shall be

included.

(5) An owner or operator may request approval to use alternatives to the continuous operating parameter monitoring and recordkeeping provisions liste d in paragraph (i) of this section.

(i) Requests shall be submitted with the Application for Approval of Construction or

Reconstruction for new sources and no later than 18 months prior to the compliance date for existing sources. The information may be su bmitted in an operating permit application, in an amendment to an operating permit application, or in a separate submittal. Requests shall contain the information specified in paragraphs (h)(5)(iii) through (h)(5)(iv) of this section, as applicable.

(ii) T he provisions in §63.8(f)(5)(i) of subpart A of this part shall govern the review and approval of requests.

(iii) An owner or operator may request approval to use an automated data compression recording system that does not record monitored operating param eter values at a set frequency (for example, once every hour) but records all values that meet set criteria for variation from previously recorded values.

(A) The requested system shall be designed to:

( 1 ) Measure the operating parameter value at least onc e every hour.Page 87 of 107

( 2 ) Record at least 24 values each day during periods of operation.

( 3 ) Record the date and time when monitors are turned off or on.

( 4 ) Recognize unchanging data that may indicate the monitor is not functioning properly, alert the operator, and record the incident.

( 5 ) Compute daily average values of the monitored operating parameter based on recorded data.

(B) The request shall contain a description of the monitoring system and data compression recording system including the criteria used to determine which monitored values are recorded and retained, the method for calculating daily averages, and a demonstration that the system meets all criteria of paragraph (h)(5)(iii)(A) of this section.

(iv) An owner or operator may request approval to us e other alternative monitoring systems according to the procedures specified in §63.8(f) of subpart A of this part.

(6) The owner or operator shall submit the information specified in paragraphs (h)(6)(i) through (h)(6)(iii) of this section, as applicable. For existing sources, this information shall be submitted in the initial Notification of Compliance Status report. For a new source, the information shall be submitted with the application for approval of construction or reconstruction required by §63.5(d ) of subpart A of this part. The information may be submitted in an operating permit application, in an amendment to an operating permit application, or in a separate submittal.

(i) The determination of applicability of this subpart to petroleum refining p rocess units that are designed and operated as flexible operation units.

(ii) The determination of applicability of this subpart to any storage vessel for which use varies from year to year.

(iii) The determination of applicability of this subpart to any d istillation unit for which use varies from year to year.

( 7 ) The owner or operator of a heat exchange system at an existing source must notify the

Administrator at least 30 calendar days prior to changing from one of the monitoring options specified in §6 3 .6 54(c) to the other

.

(i) Recordkeeping . ( 1) Each owner or operator subject to the storage vessel provisions in §63.646 shall keep the records specified in §63.123 of subpart G of this part except as specified in paragraphs (i)(1)(i) through (i)(1)(iv) of this section.

(i) Records related to gaskets, slotted membranes, and sleeve seals are not required for storage vessels within existing sources.

(ii) All references to §63.122 in §63.123 of subpart G of this part shall be replaced with §63.655(e),Page 88 of 107

(iii) All references to §63. 150 in §63.123 of subpart G of this part shall be replaced with §63.652.

(iv) 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 existi ng sources or 2 percent for new sources, a record of any data, assumptions, and procedures used to make this determination shall

be retained.

(2) Each owner or operator required to report the results of performance tests under paragraphs (f) and (g)(7) of this section shall retain a record of all reported results as well as a complete test report, as described in paragraph (f)(2)(ii) of this section for each emission point tested.

(3) Each owner or operator required to continuously monitor operating paramet ers under §63.644 for miscellaneous process vents or under §§63.652 and 63.653 for emission points in an emissions average shall keep the records specified in paragraphs (i)(3)(i) through (i)(3)(v) of this section unless an alternative recordkeeping system has been requested and approved under paragraph (h) of this section.

(i) The monitoring system shall measure data values at least once every hour.

(ii) The owner or operator shall record either:

(A) Each measured data value; or

(B) Block average values fo r 1 hour or shorter periods calculated from all measured data values during each period. If values are measured more frequently than once per minute, a single value for each minute may be used to calculate the hourly (or shorter period) block average inste ad of

all measured values.

(iii) Daily average values of each continuously monitored parameter shall be calculated for each operating day and retained for 5 years except as specified in paragraph (i)(3)(iv) of this section.

(A) The daily average shall be c alculated as the average of all values for a monitored parameter recorded during the operating day. The average shall cover a 24

- hour period if operation is continuous, or the number of hours of operation per day if operation is not continuous.

(B) The ope rating day shall be the period defined in the Notification of Compliance Status report. It may be from midnight to midnight or another daily period.

(iv) If all recorded values for a monitored parameter during an operating day are within the range

establis hed in the Notification of Compliance Status report, the owner or operator may record that all values were within the range and retain this record for 5 years rather than calculating and recording a daily average for that day. For these days, the records r equired in paragraph (i)(3)(ii) of this section shall also be retained for 5 years.Page 89 of 107

(v) Monitoring data recorded during periods of monitoring system breakdowns, repairs, calibration checks, and zero (low

- level) and high

- level adjustments shall not be inclu ded in any average computed under this subpart. Records shall be kept of the times and durations of all such periods and any other periods during process or control device operation when monitors are not operating.

(4) The owner or operator of a heat excha nge system subject to the monitoring requirements in §63.654 shall comply with the recordkeeping requirements in §65.625 paragraphs (i)(4)(i) through (vi) of this section

.

(i) Identification of all heat exchangers at the facility and the average annual HAP concentration of process fluid or intervening cooling fluid estimated when developing the Notification of Compliance Status report.

(ii) Identification of all heat exchange systems that are in organic HAP service. For each heat exchange system that is subj ect to this subpart, this must include identification of all heat exchangers within each heat exchange system, identification of the individual heat exchangers in organic HAP service within each heat exchange system, and, for closed

- loop recirculation

syst ems, the cooling tower included in each heat exchange system.

(iii) Results of the following monitoring data for each monthly monitoring event:

(A) Date/time of event.

(B) Barometric pressure.

(C) El Paso air stripping apparatus water flow (ml/min) and air flow, ml/min, and air temperature, °C.

(D) FID reading (ppmv).

(E) Heat exchange exit line flow or cooling tower return line flow at the El Paso monitoring location, gal/min.

(F) Calibration information identified in Section 5.4.2 of the Modified El Paso Method, incorporated by reference in §63.14(n).

(iv) The date when a leak was identified and the date when the heat exchanger was repaired or

taken out of service.

(vi) If a repair is delayed, the reason for the delay, the schedule for completing the repai r, and the estimate of potential emissions for the delay of repair.

(5) All other information required to be reported under paragraphs (a) through (h) of this section shall be retained for 5 years.Page 90 of 107

§ 63.656 Implementation and enforcement.

(a) This subpar t can be implemented and enforced by the U.S. EPA, or a delegated authority such as the applicable State, local, or Tribal agency. If the U.S. EPA Administrator has delegated authority to a State, local, or Tribal agency, then that agency, in addition to t he U.S. EPA, has the authority to implement and enforce this subpart. Contact the applicable U.S. EPA Regional Office to find out if implementation and enforcement of this subpart is delegated to a State, local, or Tribal agency.

(b) In delegating implemen tation and enforcement authority of this subpart to a State, local, or Tribal agency under subpart E of this part, the authorities contained in paragraph (c) of this section are retained by the Administrator of U.S. EPA and cannot be transferred to the Sta te, local, or Tribal agency.

(c) The authorities that cannot be delegated to State, local, or Tribal agencies are as specified in paragraphs (c)(1) through (4) of this section.

(1) Approval of alternatives to the requirements in §§63.640, 63.642(g) through (l), 63.643, 63.646 through 63.652, and 63.654. Where these standards reference another subpart, the cited provisions will be delegated according to the delegation provisions of the referenced subpart. Where these standards reference another subpart and m odify the requirements, the requirements shall be modified as described in this subpart. Delegation of the modified requirements will also occur according to the delegation provisions of the referenced subpart.

(2) Approval of major alternatives to test me thods under §63.7(e)(2)(ii) and (f), as defined in §63.90, and as required in this subpart.

(3) Approval of major alternatives to monitoring under §63.8(f), as defined in §63.90, and as required in this subpart.

(4) Approval of major alternatives to record keeping and reporting under §63.10(f), as defined in §63.90, and as required in this subpart.

§§ 63.657

- 63.679 [Reserved]

Appendix to Subpart CC of Part 63

— TablesPage 91 of 107

Table 1

— Hazardous Air Pollutants

Chemical name CAS No. a

Benzene 71432 Biphenyl 92524

But adiene (1,3) 106990

Carbon disulfide 75150 Carbonyl sulfide 463581 Cresol (mixed isomers b ) 1319773 Cresol (m

- ) 108394 Cresol (o

- ) 95487 Cresol (p

- ) 106445

Cumene 98828 Dibromoethane (1,2) (ethylene dibromide) 106934 Dichloroethane (1,2) 107062

Di ethanolamine 111422 Ethylbenzene 100414 Ethylene glycol 107211

Hexane 110543

Methanol 67561 Methyl isobutyl ketone (hexone) 108101 Methyl tert butyl ether 1634044 Naphthalene 91203

Phenol 108952

Toluene 108883 Trimethylpentane (2,2,4) 540841 Xyl ene (mixed isomers b ) 1330207 xylene (m

- ) 108383 xylene (o

- ) 95476 xylene (p

- ) 106423

a CAS number = Chemical Abstract Service registry number assigned to specific compounds, isomers, or mixtures of compounds.

b Isomer means all structural arrangements fo r the same number of atoms of each element and does not mean salts, esters, or derivatives.Page 92 of 107

Table 2

— Leak Definitions for Pumps and Valves

Standard a Phase Leak definition (parts per million) §63.163 (pumps) I 10,000

II 5,000

III 2,000 §63.168 (val ves) I 10,000

II 1,000

III 1,000

a Subpart H of this part.Page 93 of 107

Table 3

— Equipment Leak Recordkeeping and Reporting Requirements for Sources Complying With §63.648 of Subpart CC by Compliance With Subpart H of this Part a

Reference (section of subpart H o f

this part) Description Comment 63.181(a) Recordkeeping system requirements Except for §§63.181(b)(2)(iii) and 63.181(b)(9). 63.181(b) Records required for process unit equipment Except for §§63.181(b)(2)(iii) and 63.181(b)(9).
63.181(c) Visual inspect ion

documentation Except for §§63.181(b)(2)(iii) and 63.181(b)(9). 63.181(d) Leak detection record requirements Except for §63.181(d)(8).

63.181(e) Compliance requirements for pressure tests for batch product process equipment

trains This subsection does not apply to subpart

CC.

63.181(f) Compressor compliance test

records. 63.181(g) Closed

- vent systems and

control device record requirements. 63.181(h) Process unit quality improvement program

records. 63.181(i) Heavy liquid service

determination re cord. 63.181(j) Equipment identification

record. 63.181(k) Enclosed

- vented process

unit emission limitation record requirements.
63.182(a) Reports. 63.182(b) Initial notification report requirements. Not required.

63.182(c) Notification of complia nce status report Except in §63.182(c); change “within 90 days of the compliance dates” to “within 150 days of the compliance dates”; except in §§63.182 (c)(2) and (c)(4). 63.182(d) Periodic report Except for §§63.182 (d)(2)(vii), (d)(2)(viii), and (d)(3)

.

a This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.Page 94 of 107

Table 4

— Gasoline Distribution Emission Point Recordkeeping and Reporting Requirements a

Reference (section of

s ubpart R) Description Comment 63.428(b) or (k) Records of test results for each gasoline cargo tank loaded at the facility
63.428(c) Continuous monitoring data recordkeeping requirements 63.428(g)(1) Semiannual report loading rack

information Required to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC. 63.428(h)(1) through (h)(3) Excess emissions report loading

rack information Required to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC.

a This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.Page 95 of 107

Table 5

— Marine Vessel Loading Operations Recordkeeping and Reporting Requirements a

Reference (section of subpart Y) Description Comment 63.562(e)(2) Operation and maintenance plan for control equipment and monitoring equipment
63.565(a) Performance test/site test plan The information required under this paragraph is to be submitted with the Notification of Compli ance Status report required under 40 CFR part 63, subpart

CC. 63.565(b) Performance test data requirements 63.567(a) General Provisions (subpart A) applicability 63.567(c) Request for extension of compliance 63.567(d) Flare recordkeeping requirement s 63.567(e) Summary report and excess emissions and monitoring system performance report requirements The information required under this paragraph is to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC. 63.567(f) Vapor co llection system engineering report 63.567(g) Vent system valve bypass recordkeeping requirements 63.567(h) Marine vessel vapor

- tightness

documentation 63.567(i) Documentation file

maintenance 63.567(j) Emission estimation reporting and recordkeepin g procedures

a This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.Page 96 of 107

Table 6

— General Provisions Applicability to Subpart CC a

Reference Applies to subpart CC Comment

6 3.1(a)(1) Yes 63.1(a)(2) Yes 63.1(a)(3) Yes 63.1(a)(4) Yes 63.1(a)(5) No Reserved.
63.1(a)(6) Yes Except the correct mail drop (MD) number is C404

– 04. 63.1(a)(7)

– 63.1(a)(9) No Reserved.

63.1(a)(10) Yes 63.1(a)(11) Yes 63.1(a)(12) Yes 63.1( b)(1) Yes 63.1(b)(2) No Reserved. 63.1(b)(3) No 63.1(c)(1) Yes 63.1(c)(2) No Area sources are not subject to subpart CC.
63.1(c)(3)

– 63.1(c)(4) No Reserved.

63.1(c)(5) Yes Except that sources are not required to submit notifications overridden by t his table. 63.1(d) No Reserved.
63.1(e) No No CAA section 112(j) standard applies to the affected sources under subpart CC.

63.2 Yes §63.641 of subpart CC specifies that if the same term is defined in subparts A and CC, it shall have the meaning given

i n subpart CC.

63.3 Yes 63.4(a)(1)

– 63.4(a)(2) Yes

63.4(a)(3)

– 63.4(a)(5) No Reserved.

63.4(b) Yes 63.4(c) Yes 63.5(a) Yes 63.5(b)(1) Yes 63.5(b)(2) No Reserved. 63.5(b)(3) Yes 63.5(b)(4) Yes Except the cross

- reference to §63.9(b) is changed to §63.9(b)(4) and (5). Subpart CC overrides §63.9 (b)(2). 63.5(b)(5) No Reserved. 63.5(b)(6) YesPage 97 of 107

Reference Applies to subpart CC Comment 63.5(c) No Reserved. 63.5(d)(1)(i) Yes Except that the application shall be submitted as soon as practicable before startup, but no later than 90 days af ter the promulgation date of subpart CC if the construction or reconstruction had commenced and initial startup had not occurred before the promulgation of subpart CC. 63.5(d)(1)(ii) Yes Except that for affected sources subject to subpart CC,

emission est imates specified in §63.5(d)(1)(ii)(H) are not required. 63.5(d)(1)(iii) No Subpart CC §63.655(f) specifies Notification of Compliance Status report requirements. 63.5(d)(2) Yes 63.5(d)(3) Yes 63.5(d)(4) Yes 63.5(e) Yes 63.5(f) Yes 63.6(a) Yes 63.6(b)(1)

– 63.6(b)(5) No Subpart CC specifies compliance dates and notifications for sources subject to subpart CC. 63.6(b)(6) No Reserved. 63.6(b)(7) Yes 63.6(c)(1)

– 63.6(c)(2) No §63.640 of subpart CC specifies the compliance date.

63.6(c)(3)

– 63.6( c)(4) No Reserved.

63.6(c)(5) Yes 63.6(d) No Reserved.
63.6(e)(1) Yes Except the startup, shutdown, or malfunction plan does not apply to Group 2 emission points that are not part of an emissions averaging group. b

63.6(e)(2) No Reserved. 63.6(e)(3)(i ) Yes Except the startup, shutdown, or malfunction plan does not apply to Group 2 emission points that are not part of an emissions averaging group. b

63.6(e)(3)(ii) No Reserved. 63.6(e)(3)(iii)

– 63.6(e)(3)(ix) Yes Except the reports specified in §63.6(e)( 3)(iv) do not need to be reported within 2 and 7 days of commencing and completing the action, respectively, but must be included in the next periodic report. 63.6 (f)(1) Yes Except for the heat exchange system standards, which apply

at all times.Page 98 of 107

Reference Applies to subpart CC Comment 63.6(f )(2) and (3) Yes Except the phrase “as specified in §63.7(c)” in §63.6(f)(2)(iii)(D) does not apply because subpart CC does not require a site

- specific test plan. 63.6(g) Yes 63.6(h)(1) and 63.6(h)(2) Yes Except §63.6(h)(2)(ii), which is reserved.

63.6 (h)(3) No Reserved. 63.6(h)(4) No Notification of visible emission test not required in subpart

CC. 63.6(h)(5) No Visible emission requirements and timing is specified in §63.645(i) of subpart CC. 63.6(h)(6) Yes 63.6(h)(7) No Subpart CC does not requi re opacity standards. 63.6(h)(8) Yes 63.6(h)(9) No Subpart CC does not require opacity standards. 63.6(i) Yes Except for §63.6(i)(15), which is reserved. 63.6(j) Yes 63.7(a)(1) Yes 63.7(a)(2) Yes Except test results must be submitted in the Notifi cation of Compliance Status report due 150 days after compliance date, as specified in §63.655(f) of subpart CC.
63.7(a)(3) Yes 63.7(a)(4) Yes 63.7(b) No Subpart CC requires notification of performance test at least 30 days (rather than 60 days) prior to the performance test.
63.7(c) No Subpart CC does not require a site

- specific test plan. 63.7(d) Yes 63.7(e)(1) Yes Except the performance test must be conducted at the maximum representative capacity as specified in §63.642(d)(3) of subpart CC.

63 .7(e)(2)

– 63.7(e)(4) Yes

63.7(f) No Subpart CC specifies applicable methods and provides alternatives without additional notification or approval. 63.7(g) No Performance test reporting specified in §63.655(f). 63.7(h)(1) Yes 63.7(h)(2) Yes 63.7(h)(3 ) Yes Yes, except site

- specific test plans shall not be required, and where §63.7(g)(3) specifies submittal by the date the site

specific test plan is due, the date shall be 90 days prior to the Notification of Compliance Status report in §63.655(f).

63.7 (h)(4)(i) YesPage 99 of 107

Reference Applies to subpart CC Comment 63.7(h)(4)(ii) No Site

- specific test plans are not required in subpart CC. 63.7(h)(4)(iii) and (iv) Yes

63.7(h)(5) Yes 63.8(a) Yes Except §63.8(a)(3), which is reserved. 63.8(b) Yes 63.8(c)(1) Yes 63.8(c)(2) Yes 63.8(c)(3) Yes E xcept that verification of operational status shall, at a minimum, include completion of the manufacturer ’ s written specifications or recommendations for installation, operation, and calibration of the system or other written procedures that provide adequa te assurance that the equipment would monitor accurately.
63.8(c)(4) Yes Except subpart CC specifies the monitoring cycle frequency specified in §63.8(c)(4)(ii) is “once every hour” rather than

“for each successive 15

- minute period.”
63.8(c)(5)

– 63.8(c)(8 ) No

63.8(d) No 63.8(e) No Subpart CC does not require performance evaluations; however, this shall not abrogate the Administrator ’ s authority to require performance evaluation under section 114 of the

Clean Air Act. 63.8(f)(1) Yes 63.8(f)(2) Yes 63.8(f)(3) Yes 63.8(f)(4)(i) No Timeframe for submitting request is specified in §63.655(h)(5)(i) of subpart CC. 63.8(f)(4)(ii) Yes 63.8(f)(4)(iii) No Timeframe for submitting request is specified in §63.655(h)(5)(i) of subpart CC. 63.8(f)(5) Yes

6 3.8(f)(6) No Subpart CC does not require continuous emission monitors. 63.8(g) No Subpart CC specifies data reduction procedures in §63.655(i)(3).
63.9(a) Yes Except that the owner or operator does not need to send a copy of each notification submitted t o the Regional Office of the EPA as stated in §63.9(a)(4)(ii). 63.9(b)(1) Yes Except the notification of compliance status report specified in §63.655(f) of subpart CC may also serve as the initial compliance notification required in §63.9(b)(1)(iii).Page 100 of 107

Reference Applies to subpart CC Comment

63 .9(b)(2) No A separate Initial Notification report is not required under subpart CC. 63.9(b)(3) No Reserved. 63.9(b)(4) Yes Except for subparagraphs §63.9(b)(4)(ii) through (iv), which

are reserved. 63.9(b)(5) Yes 63.9(c) Yes 63.9(d) Yes 63.9(e) N o Subpart CC requires notification of performance test at least 30 days (rather than 60 days) prior to the performance test and does not require a site

- specific test plan. 63.9(f) No Subpart CC does not require advanced notification of visible

emissions t est. 63.9(g) No 63.9(h) No Subpart CC §63.655(f) specifies Notification of Compliance Status report requirements. 63.9(i) Yes 63.9(j) No 63.10(a) Yes 63.10(b)(1) No §63.655(i) of subpart CC specifies record retention requirements. 63.10(b)(2)(i) Yes 63.10(b)(2)(ii) Yes 63.10(b)(2)(iii) No 63.10(b)(2)(iv) Yes 63.10(b)(2)(v) Yes 63.10(b)(2)(vi) Yes 63.10(b)(2)(vii) No 63.10(b)(2)(viii) Yes 63.10(b)(2)(ix) Yes 63.10(b)(2)(x) Yes 63.10(b)(2)(xi) No 63.10(b)(2)(xii) Yes 63.10(b )(2)(xiii) No 63.10(b)(2)(xiv) Yes 63.10(b)(3) No 63.10(c)(1)

– 63.10(c)(6) No

63.10(c)(7) and 63.10(c)(8) Yes

63.10(c)(9)

– 63.10(c)(15) NoPage 101 of 107

Reference Applies to subpart CC Comment 63.10(d)(1) Yes 63.10(d)(2) No §63.655(f) of subpart CC specifies performance test reporting. 63.10(d)(3 ) No Results of visible emissions test are included in Compliance Status Report as specified in §63.655(f). 63.10(d)(4) Yes 63.10(d)(5)(i) Yes b Except that reports required by §63.10(d)(5)(i) may be submitted at the same time as periodic reports specifi ed in §63.655(g) of subpart CC. 63.10(d)(5)(ii) Yes Except that actions taken during a startup, shutdown, or malfunction that are not consistent with the startup, shutdown, and malfunction plan and that cause the source to exceed any applicable emission l imitation do not need to be reported within 2 and 7 days of commencing and completing the action, respectively, but must be included in the next periodic

report. 63.10(e) No 63.10(f) Yes

63.11

– 63.16 Yes

a Wherever subpart A specifies “postmark” dates , submittals may be sent by methods other than the U.S. Mail (e.g., by fax or courier). Submittals shall be sent by the specified dates, but a postmark is not required.

b The plan, and any records or reports of startup, shutdown, and malfunction do not appl y to Group 2 emission points that are not part of an emissions averaging group.Page 102 of 107

Table 7

— Fraction Measured (F M ), Fraction Emitted (F E ), and Fraction Removed (FR) for HAP Compounds in Wastewater Streams

Chemical name CAS No. a F
m F
e Fr

Benzene 71432 1.00 0.8 0 0.99 Biphenyl 92524 0.86 0.45 0.99 Butadiene (1,3) 106990 1.00 0.98 0.99

Carbon disulfide 75150 1.00 0.92 0.99

Cumene 98828 1.00 0.88 0.99 Dichloroethane (1,2

- ) (Ethylene dichloride) 107062 1.00 0.64 0.99 Ethylbenzene 100414 1.00 0.83 0.99

Hexane 110543 1.00 1.00 0.99

Methanol 67561 0.85 0.17 0.31 Methyl isobutyl ketone (hexone) 108101 0.98 0.53 0.99 Methyl tert butyl ether 1634044 1.00 0.57 0.99 Naphthalene 91203 0.99 0.51 0.99 Trimethylpentane (2,2,4) 540841 1.00 1.00 0.99 xylene (m

- ) 10838 3 1.00 0.82 0.99 xylene (o

- ) 95476 1.00 0.79 0.99 xylene (p

- ) 106423 1.00 0.82 0.99

a CAS numbers refer to the Chemical Abstracts Service registry number assigned to specific compounds, isomers, or mixtures of compounds.

Table 8

— Valve Monitoring Frequenc y for Phase III

Performance level Valve monitoring frequency Leaking valves a (%)

≥4 Monthly or QIP. b

<4 Quarterly.

<3 Semiannual.

<2 Annual.

a Percent leaking valves is calculated as a rolling average of two consecutive monitoring periods.

b QIP=Quali ty improvement program. Specified in §63.175 of subpart H of this part.Page 103 of 107

Table 9

— Valve Monitoring Frequency for Alternative

Performance level Valve monitoring frequency under §63.649 alternative Leaking valves a (%)

≥5 Monthly or QIP. b

<5 Quarterly.

<4 Semiannual.

<3 Annual.

a Percent leaking valves is calculated as a rolling average of two consecutive monitoring periods.

b QIP=Quality improvement program. Specified in §63.175 of subpart H of this part.Page 104 of 107

Table 10

— Miscellaneous Process Vents

— Monitoring, Re cordkeeping and Reporting Requirements for Complying With 98 Weight

- Percent Reduction of Total Organic HAP Emissions or a Limit of 20 Parts Per Million by Volume

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monito red
parameters

Thermal incinerator Firebox

temperature b (63.644(a)(1)(i)) 1. Continuous records c

.

2. Record and report the firebox temperature averaged over the full period of the performance

test

— NCS d

. 3. Record the daily average firebox tempera ture for each operating day e

. 4. Report all daily average temperatures that are outside the range established in the NCS or operating permit and all operating days when insufficient monitoring data are collected f

— PR g

. Catalytic incinerator Temperatur e upstream and downstream of the catalyst bed (63.644(a)(1)(ii)) 1. Continuous records c

.

2. Record and report the upstream and downstream temperatures and the temperature difference across the catalyst bed averaged over the full period of the performa nce

test

— NCS d

. 3. Record the daily average upstream temperature and temperature difference across the catalyst bed for each operating day e

. 4. Report all daily average upstream temperatures that are outside the range established in the NCS or ope rating permit

— PR g

.Page 105 of 107

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monito red
parameters 5. Report all daily average temperature differences across the catalyst bed that are outside the range established in the NCS or operating permit

— PR g

. 6. Report all operating days when insufficient monitoring data are

collected f

. Boiler or process heater with a design heat capacity less than 44 megawatts where

the vent stream is not
introduced into the

flame zone h,i Firebox

temperature b (63.644(a)(4)) 1. Continuous records c

.

2. Record and report the firebox temperature averaged over the full period of the performance

test

— NCS d

. 3. Record the daily average firebox temperature for each operating day e

. 4. Report all daily average firebox temperatures that are outside the range es tablished in the NCS or operating permit and all operating days when insufficient monitoring data are

collected f

— PR g

. Flare Presence of a flame at the pilot light (63.644(a)(2)) 1. Hourly records of whether the monitor was continuously operating and wheth er a pilot flame was continuously present during each hour. 2. Record and report the presence of a flame at the pilot light over the full period of the compliance

determination

— NCS d

. 3. Record the times and durations of all periods when all pilot

flames for a flare are absent or the monitor is not operating.Page 106 of 107

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monito red
parameters 4. Report the times and durations of all periods when all pilot

flames for a flare are absent or the monitor is not operating.

All control devices Presence of flow diverted to the

atmosp here from the control device (63.644(c)(1)) or 1. Hourly records of whether the flow indicator was operating and whether flow was detected at any time during each hour. 2. Record and report the times and durations of all periods when

the vent stream is diverted through a bypass line or the monitor is not operating

— PR g

. Monthly inspections of sealed valves [63.644(c)(2)] 1. Records that monthly inspections were performed. 2. Record and report all monthly inspections that show the valves

are no t closed or the seal has been changed

— PR g

.

a Regulatory citations are listed in parentheses.

b Monitor may be installed in the firebox or in the ductwork immediately downstream of the firebox before any substantial heat exchange is encountered.

c “Continuous records” is defined in §63.641.

d NCS = Notification of Compliance Status Report described in §63.655.

e The daily average is the average of all recorded parameter values for the operating day. If all recorded values during an operating day are within the r ange established in the NCS or operating permit, a statement to this effect can be recorded instead of the daily average.

f When a period of excess emission is caused by insufficient monitoring data, as described in §63.655(g)(6)(i)(C) or (D), the duration of the period when monitoring data were not collected shall be included in the Periodic Report.

g PR = Periodic Reports described in §63.655(g).

h No monitoring is required for boil ers and process heaters with a design heat capacity ≥44 megawatts or for boilers and process heaters where all vent streams are introduced into the flame zone. No recordkeeping or reporting associated with monitoring is required for such boilers and

proces s heaters.Page 107 of 107

i Process vents that are routed to refinery fuel gas systems are not regulated under this subpart. No monitoring, recordkeeping, or reporting is required for boilers and process heaters that combust refinery fuel gas.