June 11, 2013 Redline of 40 CFR part 63, subpart CC, showing final amendments Insertions are shown in bold blue text Deletions are shown inred strikeout text

Title 40: Protection of Environment

PART 63—NATIONAL EMISSION STANDAR DS FOR HAZARDOUS AIR POLLUTANTS FOR SOURCE CATEGORIES Subpart CC—National Emission Standards for Hazardous Air Pollutants From Petroleum Refineries § 63.640 Applicability and designation of affected source. (a) This subpart applies to petroleum refining pro cess 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 paragrap hs (a)(1) and (2) of this section: (1) Are located at a plant site that is a major sour ce as defined in section 112(a) of the Clean Air Act; and (2) Emit or have equipment cont aining or contacting one or more of the hazardous air pollutants listed in table 1 of this subpart. (b)(1) If the predominant us e of the flexible opera tion unit, as described in paragraphs (b)(1)(i) and (ii) of this secti on, is as a petroleum re fining process unit, as defined in §63.641, then the flexible operation unit sha ll be subject to the prov isions 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 greates t annual operating time. (ii) If the flexible oper ation unit is used as a petroleum re fining 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 pro duces the greatest annual production on a mass basis. (2) The determination of applicabil ity of this subpart to petroleum refining process units that are designed and operated as flexible operation units shall be report ed as specified in §63.655(h)(6)(i).Page 2 of 109

(c) For the purposes of this subpart, the affected source shall comprise all emissions points, in combination, listed in paragraphs (c)(1) through (c)(8) of this secti on that are located at a single refinery plant site. (1) All miscellaneous process vents from petroleu m refining process units meeting the criteria in paragraph (a) of this section; (2) All storage vessels associated with petroleum refining process units m eeting the criteria in paragraph (a) of this section; (3) All wastewater streams and treatment operati ons associated with petroleum refining process units meeting the criteria in pa ragraph (a) of this section; (4) All equipment leaks from petroleum refining pr ocess units meeting the criteria in paragraph (a) of this section; (5) All gasoline loading racks classified under Standard Indus trial Classification code 2911 meeting the criteria in paragr aph (a) of this section; (6) All marine vessel loading op erations located at a petroleum refinery me eting the criteria in paragraph (a) of this sect ion and the applicab ility criteria of subpart Y, §63.560; (7) All storage vessels and equipment leaks associ ated with a bulk gasolin e terminal or pipeline breakout station classified under Standard Industrial Cl assification code 2 911 located within a contiguous area and under common c ontrol with a refinery meeting the criteria in paragraph (a) of this section; and (8) All heat exchange systems , associated with petroleum refi ning process units meeting the criteria in paragraph (a) of this section and w hich are in organic hazardous air pollutants (HAP) service as defined in this subpart. (d) The affected source subject to this subpart does not include the emissi on 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 devi ce, sampling connection system, open-ended valve or line, valve, or instrumentation system that is intended to op erate in organic hazardous air pollutant service, as defi ned in §63.641 of this subpart, fo r less than 300 hours during the calendar year; (4) Catalytic cracking unit and cat alytic reformer catalyst regeneration vents, and sulfur plant vents; andPage 3 of 109

(5) Emission points routed to a fuel gas system, as defined in §63.641 of this subpart. No testing, monitoring, recordkeeping, or reporting is require d for refinery fuel ga s 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 inparagraphs (e)(1) and (e)(2) of this section to determine whether a storage vessel is part of a source to which this subpart applies. The owner or operator of a storage vessel constructe d after August 18, 1994, shall follow the procedures specified in paragraphs (e)(1), (e)(2)(i), and (e)(2)(ii) of this se ction to determine whether a storage vessel is part of a source to whic h 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 process unit is a petrol eum refining process unit subject to this subpart, then the storage vessel is part of the affected sour ce to which this subpart applies. (ii) If the process unit is not subj ect to this subpart, then the st orage vessel is not part of the affected source to which this subpart applies. (2) If a storage vessel is not dedicated to a sing le process unit, then the applicability of this subpart shall be determined according to the provis ions in paragraphs (e)(2)(i) through (e)(2)(iii) of this section. (i) If a storage vessel is shared among proce ss 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 greatest i nput on a volume basis into the storage vessel is fro m a process unit that is located on the same plant site, then that process unit has th e predominant use. (B) If the greatest input on a volume basis into th e storage vessel is pr ovided from a process unit that is not located on th e same plant site, then the predominan t use shall be the process unit that receives the greatest amount of material on a volume basis from th e storage vessel at the same plant site. (ii) If a storage vessel is shared among process un its so that there is no single predominant use, and at least one of those process units is a petroleum re fining 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 petroleu m refining process unit is su bject 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 use of a storage vessel vari es from year to year, th en the applicability of this subpart shall be determined based on the ut ilization of that storage vessel during the yearPage 4 of 109

preceding August 18, 1995. This determinati on shall be reported as specified in §63.655(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 distill ation unit is part of a source to which this subpart applies. The owner or operator of a distillation un it constructed after August 18, 1994, shall follow the procedures sp ecified in paragraphs (f)(1) th rough (f)(5) of this section to determine whether a miscellaneous process vent fr om a distillation unit is part of a source to which this subpart applies. (1) If the greatest input to the distillation unit is fr om a process unit locat ed on the same plant site, then the distillation unit shall be assigned to that process unit. (2) If the greatest input to the di stillation unit is provided from a process unit that is not located on the same plant site, thenthe distillation unit shall be assigned to the process uni t located at the same plant site that receives the greatest amount of material from the distillation unit. (3) If a distillation unit is shared among process units so that th ere is no single pr edominant use, as described in paragraphs (f)(1) and (f)(2) of this section, and at least one of those process units is a petroleum refining process unit subject to this subpar t, 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 subpart, the owner or op erator 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 stre am contains greater th an 20 parts per million by volume total organic haza rdous air pollutants, then the ve nt 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 di stillation unit varies from year to year, then the applicability of this subpart shall be determined based on the ut ilization of that distilla tion unit during the year preceding August 18, 1995. This determinati on shall be reported as specified in §63.655(h)(6)(iii). (g) The provisions of th is subpart do not apply to the processes specifie d in paragraphs (g)(1) through (g)(7) of this section. (1) Research and development facilities, regardle ss 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 h azardous air pollutants listed in table 1 of this subpart that is located within a petroleum refining process unit th at is subject to this subpart;Page 5 of 109

(3) Units processing natural gas liquids; (4) Units that are used specifica lly for recycling discarded oil; (5) Shale oil extraction units; (6) Ethylene processes; and (7) Process units and emission po ints subject to subparts F, G, H, and I of this part. (h) Except as provided in paragraphs (k), (l), or (m) of this secti on, sources subject to this subpart are required to achieve compliance on or before the dates specif ied in paragraphs (h)(1) through (h)(6) of this section. (1) Except as provided in paragraphs (h)(1)(i) and (i i v ) of this section, new sources that commence construction or recons truction after July 14, 1994, shall be in compliance with this subpart upon initial startup or August 18, 1995, whichever is later. (i) [Reserved] (ii) Heat exchange systems a A t new sources that commence cons truction or reconstruction after July 14, 1994 August 18, 1995 , but on or before September 4, 2007, heat exchange systems shall be in compl iance ywith the existing source requirements for heat exchange systems specified in §63.654 no late r than October 29, 2012. (iii) [Reserved] (i i v ) Heat ex change systems a A t new sources that commence cons truction or reconstruction after September 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 paragr aphs (h)(3) through (h)(6) of this section, existing sources shall 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 extens ion has been granted by the Administrator as provided in §63.6( i) of subpart A of this part. (3) Marine tank vessels at existing sources shall be in compliance w ith this subpart no later than August 18, 1999 unless the vess els are included in an emission s average to generate emission credits. Marine tank vessels usedto generate credits in an emissions average shall be in compliance with this subpart no later than A ugust 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 subpart at the first degass ing and cleaning activity afte r August 18, 1998, or August 18, 2005, whichever is first.Page 6 of 109

(5) An owner or operator may elect to complywith the provisions of §63.648 (c) through (i) as an alternative to the pr ovisions of §63.648 (a) and (b). In such cases, the owner or operator shall comply no later than the dates speci fied in paragraphs (h)(5)(i) thr ough (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 this subpart), beginning no later than August 18, 1999; and (iii) Phase III (see table 2 of this subpart), beginning no later than February 18, 2001. (6) Heat exchange systems at anexisting source shall be in co mpliance with the existing source standards in §63.654 no late r 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 addi tion shall be subject to the requirements for a new source if it meets the criteria sp ecified in paragraphs (i)(1) through (i)(3) of this section: (1) It is an addition that meet s the definition of cons truction in §63.2 of subpa rt A of this part; (2) Such construction commen ced after July 14, 1994; and (3) The addition has the potential to emit 10 tons per year or more of any hazardous air pollutant or 25 tons per year or mo re 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 so urce 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 recons truction in §63.2 of subpart A of this part; and (2) Such reconstruction co mmenced 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 an d the addition or change is dete rmined to be subject to the new source 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 complian ce 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 so urce, addition, or change shall comply with the reporting and recordkeeping requir ements that are applicable to new sources. The applicable reports include, but are not limited to:Page 7 of 109

(i) The application for approval of construction or re construction shall be submitted as soon as practical before the construction or reconstruction is planned to commence (but itneed 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; (iii) Periodic Reports and other repor ts as required by §63.655(g) and (h); (iv) Reports and notificati ons required by §60.487 of subpart VV of part 60 or §63.182 of subpart H of this part. The requi rements for subpart H are summarize d in table 3 of this subpart; (v) Reports required by 40 CFR 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. These requiremen ts are summarized in tabl e 4 of this subpart; and (vii) Reports and notifications required by §§63.565 and 63.567 of subpart Y of this part. These requirements 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, gaso line loading rack, marine tank ve ssel loading operation, or heat exchange system that meets the cr iteria in paragraphs (c)(1) thr ough (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 ma de 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 sect ion, 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, re moval, or addition of recovery equipment. For purposes of this paragraph and paragraph (m) of this section, proce ss changes do not include: Process upsets, unintentional temporary process changes, a nd changes that are within the equipment configuration and operat ing conditions documented in the No tification of Compliance Status report required by §63.655(f). (1) The added emission point(s) and any emis sion point(s) within th e added or changed petroleum refining process unit are subject to the requireme nts for an existing source. (2) The added emission point(s) and any emis sion point(s) within th e added or changed petroleum refining process unit shal l 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 emis sion point(s) is added to any existing petroleum refining pr ocess unit, the added emission point(s) shall be in compliancePage 8 of 109

upon initial startup of any added petroleum re fining process unit or emission point(s) or by August 18, 1998, whichever is later. (ii) If a deliberate operationa l process change to an existi ng 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 operato r demonstrates to the Administra tor that achieving compliance will take longer than making the change. If this demonstration is made to the Administrator’s satisfaction, the owner or operator shall follow the procedur es in paragraphs (m)(1) through (m)(3) of this section to es tablish a compliance date. (3) The owner or operator of a petroleum refining process unit or of a storage vessel, miscellaneous process vent, wastewater stre am, gasoline loading rack, marine tank vessel loading operation, or heat exchange system meeting the criter ia in paragraphs (c)(1) through (8) of this section that is added to a plant site and is subject to th e requirements for existing sources shall comply with the reporting and recordkeepi ng requirements that are applicable to existing sources including, but not limited to, the reports listed in paragraphs (l)(3)(i) through (vii) of this section. A process change to an existing petroleum refining proce ss unit shall be subject to the reporting requirements for existing sources including, but not limit ed to, the reports listed in paragraphs (l)(3)(i) throu gh (l)(3)(vii) of this s ection. The applicable repo rts 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 repor ts as required by §63.655(g) and (h); (iii) Reports and notificati ons 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 notificat ions required by §63.182, or 40 CFR 60.487. The requirements of subpart H of this part are summari zed 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. These requiremen ts are summarized in tabl e 4 of this subpart; and (vii) Reports and notifications require d 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 de vices, 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 fo r existing sources in §63.648. A notification of compliance status report shall not be required for such added equipment.Page 9 of 109

(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 su bpart, and the change causes a Group 2 emission point to become a Group 1 emis sion point (as defined in §63.641) , then the owner or operator shall comply with the requirements of this s ubpart for existin g sources for the Group 1 emission point as expeditiously as practicable, but in no event later th an 3 years after the emission point becomes Group 1. (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 schedul e shall be submitted within 180 days after the change is made, unless the compliance schedule has been previously su bmitted to the pe rmitting authority. If it is not possible to determine un til after the change is implemented whether the emission point has become Group 1, the compliance sc hedule shall be submitted within 180 days of the date when the affect of the change is know n 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 Administrator shall appr ove or deny the compliance schedul e or request changes within 120 calendar days of receipt of the compliance sc hedule and justification. Approval is automatic if not received from the Administrator within 120 calendar days of receipt. (n) Overlap of subpart CC with ot her regulations for storage vessels. (1) After the compliance dates sp ecified in paragraph (h) of th is section, a Group 1 or Group 2 storage vessel that is part of an existing source and is also su bject to the provisions of 40 CFR part 60, subpart Kb, is required to comply only with the requirem ents of 40 CFR part 60, subpart Kb, except as provided in para graph (n)(8) of this section. (2) After the compliance dates speci fied in paragraph (h) of this section a Group 1 storage vessel that is part of a new s ource and is subject to 40 CFR part 60 , subpart Kb is required to comply only with this subpart. (3) After the compliance dates speci fied 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 comp ly only with 40 CFR part 60, subpa rt Kb except as provided in paragraph (n)(8) of this section. (4) After the compliance dates speci fied 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 no t 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 speci fied in paragraph (h) of this section a Group 1 storage vessel that is also subject to the provisions of 40 CFR part 60, subp arts K or Ka is required to only comply with the provis ions of this subpart.Page 10 of 109

(6) After compliance dates specified in paragrap h (h) of this section, a Group 2 storage vessel that is subject to the control requirements of 40 CFR part 60, s ubparts K or Ka is required to comply only with the provisions of 40 CFR part 60, subparts K or Ka exce pt as provided for in paragraph (n)(9) of this section. (7) After the compliance dates speci fied 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 c ontrol requirements of 40 CFR part 60, subparts K or Ka, is requir ed to comply only with this subpart. (8) Storage vessels described by para graphs (n)(1) and (n)(3) of th is 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 s ubpart 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 dete rmines that it is unsafe to pe rform the seal gap measurements required in §60.113b(b) of subpart Kb or to insp ect the vessel to determine compliance with §60.113b(a) of subpart Kb because the roof appe ars to be structurally unsound and poses an imminent danger to inspecting personnel, the owner or oper ator 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 required by §60.113b( b)(1), and the vessel cannot be repaired within 45 days and the vessel cannot be emptie d within 45 days, the owner or operator may utilize up to two extensions of up to 30 additional calendar days ea ch. The owner or operator is not required to provide a request for the exte nsion 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 listed in §60.113b(a)(2) or §60.113b(b)(4)(iii ), and describe the nature and date of the re pair made or provide the date the stor age vessel was emptied. (v) Owners and operators of stor age vessels complying with subpa rt Kb of part 60 may submit the inspection reports required by §§60.115b(a)(3), (a)(4), a nd (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 seal in spections specified in §60.115b(b)(2) are not required if none of the measured gaps or calculated gap areas ex ceed the limitations specified in §60.113b(b)(4). Documentation of the inspect ions shall be recorded as specified in§60.115b(b)(3). (9) Storage vessels described by pa ragraph (n)(6) of this section that are to comply with 40 CFR part 60, subpart Ka, are to comply with only subp art Ka except as provid ed for in paragraphs (n)(9)(i) through (n )(9)(iv) of th is section.Page 11 of 109

(i) If the owner or operator dete rmines that it is unsafe to pe rform the seal gap measurements required in §60.113a(a)(1) of subpart Ka because th e floating roof appears to be structurally unsound and poses an imminent danger to inspect ing 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. (ii) If a failure is detected during the seal gap measuremen ts required by §60.113a(a)(1) of subpart Ka, and the vessel cannot be repaired within 45 days a nd the vessel cannot be emptied within 45 days, the owner or operator may utili ze 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 pe riodic report, identify the vessel, describe the nature and date of the repair made or provide the date the storage vessel was emptie d. The owner or operator shall also provide documentation of the decision to utilize an extensi on including a description of the failure, documentation that alte rnate storage capacity is unavaila ble, and a schedule of actions that will ensure that the contro l equipment will be re paired or the vessel emptied as soon as possible. (iv) Owners and operators of st orage vessels complying with s ubpart 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 subpa rt, rather than within th e 60-day period specified in §60.113a(a)(1)(i)(E) of subpart Ka. (o) Overlap of this subpart CC with other regulations for wastewater. (1) After the compliance dates sp ecified in paragraph (h) of th is section a Group 1 wastewater stream managed in a piece of equi pment that is also subject to the provisions of 40 CFR part 60, subpart QQQ is required to comp ly only with this subpart. (2) After the compliance dates sp ecified in paragraph (h) of th is section a Group 1 or Group 2 wastewater stream that is conv eyed, stored, or treated in a wa stewater stream management unit that also receives streams subject to the provisions of §§63.133 through 63.147 of subpart G wastewater provisions of this partshall comply as specified in pa ragraph (o)(2)(i) or (o)(2)(ii) of this section. Compliance with the provisions of paragraph (o)(2) of this section shall constitute compliance with the requirem ents 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 cont rol of the Group 1 or Gr oup 2 wastewater stream. (C) The provisions in §§63.143 th rough 63.148 of subpart G for monitoring and inspections of equipment and for recordkeeping and reporting re quirements. The owner or operator is notPage 12 of 109

required to comply with the monitoring, recordke eping, and reporting requ irements 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. (A) Comply with the provisions of § §63.133 through 63.148 and §§63.151 and 63.152 of subpart G. (B) For any Group 2 wastewater st ream or organic stream whose benzene emissions are subject to control through the use of one or more treatme nt processes or waste management units under the provisions of 40 CFR part 61, subpart FF on or after December 31, 1992, comply with the requirements of §63.133 through §63.147 of subp art G for Group 1 wastewater streams. (p) Overlap of subpart CC with othe r regulations for equipment leaks. (1) After the compliance dates speci fied 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 w ith the provisions spec ified in this subpart. (2) Equipment 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 w ith local or State regulations, the permitting authority for the affected source may allow c onsolidation of the monitoring, recordkeeping, and reporting requirements under this subpart with the monitoring, recordkeep ing, and reporting requirements under other applicable requirem ents in 40 CFR parts 60, 61, or 63, and in any 40 CFR part 52 approved State implementation plan provided th e implementation plan allows for approval of alternative monitoring, reporting, or recordkeeping requirements and provided that the permit contains an equivalent degree of compliance and control. (r) Overlap of subpart CC with other regulations for gasoline load ing 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 also 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 m eaning given them in the Clean Air Act, subpart A of this part, and in this secti on. If the same term is defined in subpart A and in this section, it shall have the meaning given in this s ection for purposes of this subpart. Affected source means the collection of emission points to which this subpart applies as determined by the criteria in §63.640.Page 13 of 109

Aliphatic means open-chained structure consisting of paraffin, olefinand acetylene hydrocarbons and derivatives. Annual average true vapor pressure means the equilibrium partial pr essure exerted by the stored liquid at the temperature equal to the annual aver age of the liquid storage temperature for liquids stored above or below the ambi ent temperature or at the local annual average temperature reported by the National Weather Service for liquids stored at the ambient temperature, as determined: (1) In accordance with methods specified in §63.111 of subpart G of this part; (2) From standard re ference texts; or (3) By any other method approv ed by the Administrator.

Boiler means any enclosed combustion de vice that extracts useful en ergy in the form of steam and is not an incinerator. By compound means by individual stream compon ents, not by carbon equivalents.

Car-seal means a seal that is placed on a device thatis used to change the position of a valve (e.g., from opened to closed) in such a way that the position of the va lve cannot be changed without breaking the seal. Closed vent system means a system that is no t open to the atmosphere and is configured of piping, ductwork, connections, and, if necessary, flow inducing de vices that transport 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 re finery fuel gas system), the process shall not be considered a closed vent sy stem and is not subject to closed vent system standards.

Combustion device means an individual unit of equipment su ch 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 fittin gs used to connect two pipe lines or a pipe line and a piece of equi pment. A common connector is a flange. Joined fittings welded completely around the circumfere nce of the interface are not considered conn ectors for the purpose of this regulation. For the purpose of repor ting 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 ev ery hour and recorded at the frequency sp ecified 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.Page 14 of 109

Control device means any equipment used for recove ring, removing, or oxidizing organic hazardous air pollutants. Such equipment includ es, but is not limited to, absorbers, carbon adsorbers, condensers, incinerators, flares, bo ilers, and process heaters. For miscellaneous process vents (as defined in this section), recove ry devices (as defined inthis section) are not considered control devices. Cooling tower means a heat removal device used to remove the heatabsorbed 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 th e cooling tower before exposure to the atmosphere. Delayed coker vent means a vent that is typically intermitt ent in nature, and usually occurs only during the initiation of the de pressuring cycle of the decoki ng operation when vapor from the coke drums cannot be sent to the fractionator column for product recovery, but instead is routed to the atmosphere throug h a closed blowdown system or direct ly to the atmosphere in an open blowdown system. The emissions from the decoking phases of de layed coker operations, which include coke drum deheading, dr aining, or decoking (coke cutti ng), are not considered to be delayed coker vents.

Distillate receiver means overhead receivers, overhead accumulators, reflux drums, and condenser(s) including eject or-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, each ex it stream having component con centrations diff erent 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 a nd condensation as they approach equilibrium within the distillation unit. Distillation unit incl udes the distill ate receiver, reboiler, and any associated vacuum pump or steam jet. Emission point means an individual mis cellaneous process vent, storage vessel, wastewater stream, or equipment leak asso ciated with a petroleum refi ning process unit; an individual storage vessel or equipment leak associated with a bulk gasolin e terminal or pipeline breakout station classified under Standa rd Industrial Classifi cation code 2911; a ga soline loading rack classified under Standard Indus trial Classification co de 2911; or a marine tank vessel loading operation located at a petroleum refinery. Equipment leak means emissions of organi c hazardous air pollutants from a pump, compressor, pressure relief device, sampling connection sy stem, open-ended valve or line, valve, or instrumentation system “in organic hazardous air po llutant service” as defined in this section. Vents from wastewater collection and conveyan ce systems (including, but not limited to wastewater drains, sewer vents, and sump drai ns), tank mixers, and sa mple valves on storage tanks are not equipment leaks.Page 15 of 109

Flame zone means the portion of a combus tion chamber of a boiler or process heater occupied by the flame envelope crea ted by the primary fuel. Flexible operation unit means a process unit that manufactur es different products periodically by alternating raw materials or oper ating conditions. Thes e units are also refe rred to as campaign plants or blocked operations.

Flow indicator means a device that 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 onsit e piping and control system that gathers gaseous streams generated by refinery operations, may blend them with sources of ga s, 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 locat ed 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 hydrocarb ons, hydrogen and other mi scellaneous species.

Gasoline means any petroleum distillate or petroleu m 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 valves, 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 th at is located within a bulk gasoline terminal that has a gasoline throughput greater than 75,700 liters per day. Gaso line throughput shall be the maximum calculated design throughput for the term inal as may be limi ted by compliance with enforceable conditions under Federal, State, or local law and discoveredby the 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 th at loads liquid commodities with vapor pressures greater than or equal to 10.3 kilopascals in bulk onto marine tank vessels, that emits grea ter than 9.1 megagrams of any individual HAP or 22.7 megagram s of any combination of HA P annually after August 18, 1999, or a vessel at a new source loadedat any land- or sea- based terminal or stru cture that loads liquid commodities with vapor pressure s 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 emi ssions are greater than or equa l 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 to any control device and prior to discharge to the atmosphere.Page 16 of 109

Group 1 storage vessel means a storage vessel at an existi ng source that has a design capacity greater than or equal to 177 cubic meters and stored-liquid maxi mum true vapor pressure greater than or equal to 10.4 kilo pascals and stored-liquid annual av erage true vapor pressure greater than or equal to 8.3 kilopascal s and annual average HAP liquid concentration greater than 4 percent by weight total organic HAP; a storage vessel at a new s ource that has a design storage capacity greater than or equal to 151 cubic meters and stored-liquid maximum true vapor pressure greater than or equa l to 3.4 kilopascals and annual average HAP liquid concentration greater than 2 percent by weight total organic HAP; or a storage vessel at a new source that has a design storage capacity grea ter than or equal to 76 cubic me ters and less than 151 cubic meters and stored-liquid maximum true vapor pressure greater than or equal to 77 kilopascals and annual average HAP liquid concentration greater than 2 percen t 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 me gagrams per year or greater as calculated according to the procedures in 40 CFR 61.342 of subpart FF of part 61 that has a flow ra te 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 requireme nts 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 de finition of a Group 1 gasoline loading rack. Group 2 marine tank vessel means a marine tank vessel that do es not meet the definition of a Group 1 marine tank vessel. Group 2 miscellaneous process vent means a miscellaneous process ve nt that does not meet the definition of a Group 1 mis cellaneous process vent. Group 2 storage vessel means a storage vessel that does not meet the defi nition 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 cont act of the process fl uid with the water ( i.e., non-contact heat exchanger) and to transport and/or cool the wate r in a closed-loop recirculation system (cooling tower system ) or a once-through system ( e.g., river or pond water). For closedloop recirculation systems, the heat exchange system consists of a cooling tower, all petroleum refinery process unit heat exchangers that are in organic HAP service, as defined in this subpart, serviced by that cooling tower, a nd all water lines to and from the se petroleum refinery process unit heat exchanger ( s ) . For once-through systems, the heat exchange system consists of all one or more heat exchangers that are in organic HAP serv ice, as defined in thisPage 17 of 109

subpart, servicing an individual petroleum refinery process unit and all wa ter lines to and from the heat exchanger ( s )

. Sample coolers or pump seal coolers are not considered heat exchangers for the purpose of this definition and are not part of the heat exchange system

. Intentional direct contact with process fluids results in the format ion of a wastewater. Heat exchanger exit line means the cooling water line from the exit of one or more heat exchangers (where cooling water le aves the 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.

Incinerator means an enclosed combustion device that is used for destroying 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 secti on; rather, the energy recovery section is a separate section following the combustion s ection and the two are jo ined by ducts or conn ections carrying flue gas. In heavy liquid service means that the piece of equipment is not in gas/vapor se rvice 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 or in organic HAP service means that a piece of equipment either contains or contact s a fluid (liquid or gas) that is at least 5 percent by weight of total organic HAP ’ s as determined according to the provi sions of §63.180(d) of subpart H of this part and table 1 of this su bpart. 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 ex ternal actuating mechanism. Maximum true vapor pressure means the equilibrium pa rtial pressure exerte d by the stored liquid at the temperature equal to the highest calendar -month average of the liquid storage temperature for liquids stored above or be low the ambient temperature or at the local maximum monthly average temperature as reported by the National Weather Service for liquids stored at the ambient temperature, as determined: (1) In accordance with methods specified in §63.111 of subpart G of this part; (2) From standard re ference texts; or (3) By any other method approv ed by the Administrator. Miscellaneous process vent means a gas stream containing grea ter than 20 parts per million by volume organic HAP that is conti nuously or periodically discha rged during normal operation of a petroleum refining process uni t meeting the criter ia specified in §63.640(a). MiscellaneousPage 18 of 109

process vents include gas streams that are discharg ed directly to the atmo sphere, gas streams that are routed to a control device prior to discharge to the atmosp here, or gas streams that are diverted through a product recove ry device prior to control or discharge to the atmosphere. Miscellaneous process vents include vent stream s from: caustic wash accumulators, distillation tower condensers/accumulators, flash/knockout dr ums, reactor vessels, scrubber overheads, stripper overheads, vacuum (s team) ejectors, wash tower over heads, water wash accumulators, blowdown condensers/accumulators, and delayed coker vents. Miscella neous process vents do not include: (1) Gaseous streams routed to a fuel gas system; (2) Relief valve discharges; (3) Leaks from equipmen t regulated under §63.648; (4) Episodic or nonroutine releases such as those associated with startup, shutdown, malfunction, maintenance, depressuring, and catalyst transfer operations; (5) In situ sampling syst ems (onstream analyzers); (6) Catalytic cracking unit cat alyst regeneration vents; (7) Catalytic reformer regeneration vents; (8) Sulfur plant vents; (9) Vents from control devices such as scrubbers, boilers, in cinerators, and electrostatic precipitators applied to catalyt ic cracking unit catalyst regenera tion vents, catalytic reformer regeneration vents, and sulfur plant vents; (10) Vents from any stripping oper ations 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, de heading, draining, or dec oking (coke cutting) or pressure testing after decoking; (12) Vents from storage vessels; (13) Emissions from wastewater collection and conveyance systems including, but not limited to, wastewater drains, sewer ve nts, and sump drains; and (14) Hydrogen production plant vents through which carbon dioxide is removed from process streams or through which steam co ndensate produced or treated within the hydrogen plant is degassed or deaerated.Page 19 of 109

Operating permit means a permit required by 40 CFR parts 70 or 71. Organic hazardous air pollutant or organic HAP in this subpart, mean s any of the organic chemicals listed in tabl e 1 of this subpart.

Petroleum-based solvents means mixtures of aliphatic hydro carbons or mixtures of one and two ring aromatic hydrocarbons. Periodically discharged means discharges that are intermitt ent and associated with routine operations. Discharges associated with main tenance activities or process upsets are not considered periodically discharg ed miscellaneous process vents and are therefore not regulated by the petroleum refinery miscella neous 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 Industria l Classification code for petroleum refining (2911), and used pr imarily for the following: (1) Producing transportation fuels (such as gasoline, diesel fuels, and jet fuels) , heating fuels (such as kerosene, fuel gas distilla te, and fuel oils), or lubricants; (2) Separating petroleum; or (3) Separating, cracking, reacting, or refo rming intermediate petroleum streams. (4) Examples of such units in clude, but are not limited to, petroleum-based solvent units, alkylation units, catalytic hyd rotreating, catalytic hydrorefin ing, catalytic hydrocracking, catalytic reforming, catalytic cracking, crud e distillation, lube o il processing, hydrogen production, isomerization, polymer ization, thermal processes, a nd blending, sweetening, and treating processes. Petroleum refining process units also include sulfur plants.

Plant site means all contiguous or adjoining propertythat is under co mmon control including properties that are separated only by a road or other public right-of-way. Common control includes properties that are ow ned, leased, or operated by the same entity, parent entity, subsidiary, or any combination thereof. Primary fuel means the fuel that provides the principal heat input (i.e., more than 50 percent) to the device. To be considered pr imary, the fuel must be able to sustain operation without the addition of other fuels.

Process heater means an enclosed combusti on device that primarily tr ansfers heat liberated by burning fuel directly to proce ss streams or to heat transfer liquids other than water.

Process unit means the equipment assembled and connect ed by pipes or ducts to process raw and/or intermediate mate rials and to manufacture an intended product. A process unit includes any associated storage vessels. Fo r the purpose of this subpart, process unit includes, but is not limited to, chemical manufacturing process units and petrol eum refining process units.Page 20 of 109

Process unit shutdown means a work practice or operationa l procedure that stops production from a process unit or part of a process unit duri ng which it is technical ly feasible to clear process material from a process un it or part of a process unit cons istent with safety constraints and during which repairs can 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 proce ss unit shutdown. An unscheduled work practice or operational procedure that would stop product ion from a process unit or part of a process unit for a shorter period of time than would be re quired to clear the process unit or part of the process unit of materials and start up the unit, or would result in greater emissions than delay of repair of leaking components until the next scheduled process un it shutdown is not considered a process unit shutdown. The use of spare equipm ent and technically feasible byp assing of equipment without stopping production are not consid ered process unit shutdowns. Recovery device means an individual unit of equipment cap able of and used for the purpose of recovering chemicals for use, reus e, or sale. Recovery devices include, but are not limited to, absorbers, carbon adsorbers, and condensers. Reference control technology for gasoline loading racks means a vapor collec tion 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 fo r miscellaneous process vents means a combustion device used to reduce organic HAP emissions by 98 percent, or to an outletconcentration of 20 parts per million by volume. Reference control technology for storage vessels means either: (1) An internal floating roof meeting the speci fications of §63.119(b) of subpart G except for §63.119 (b)(5) and (b)(6); (2) An external floati ng roof meeting th e specifications of §63.119(c) of subpart G except for §63.119(c)(2); (3) An external floating roof converted to an in ternal floating roof meet ing the specifications of §63.119(d) of subpart G excep t for §63.119(d)(2); or (4) A closed-vent system to a control device th at reduces organic HAP emissions by 95-percent, or to an outlet concentration of 20 parts per million by volume. (5) For purposes of emissions av eraging, these four technologies are considered equivalent. Reference control technology for wastewater means the use of:Page 21 of 109

(1) Controls specified in §§61.343 thr ough 61.347 of subpart FF of part 61; (2) A treatment process that achiev es the emission reductions specifi ed in table 7 of this subpart for each individual HAP present in the wastewater stream or is a steam stripper that meets the specifications in §63.138(g) of s ubpart G of this part; and (3) A control device to reduce by 95 percent (or to an outlet concen tration of 20 parts per million by volume for combustion devices) the organic HAP emissions in the vapor streams vented from 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 petr ochemical processes and that is separated for use as a fuel in boilers and process heater s throughout the refinery. Relief valve means a valve used only to release an unplanned, nonr outine discharge. A relief valve discharge can result from anoperator error, a malfunction such as a power failure or equipment failure, or other un expected 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 pl ant operations whose primary purpose is to conduct re search and development into new processes and products, where the operations are under the close supe rvision of technically trained pe rsonnel, and is not engaged in the manufacture of products for commercial sale, except in a de minimis manner.

Shutdown means the cessation of a petr oleum refining process unit or a unit operation (including, but not limited to, a di stillation unit or reactor) within a petroleum refining process unit for purposes including, but not limited to, periodic ma intenance, replacement of equipment, or repair. Startup means the setting into operation of a petr oleum refining process unit for purposes of production. Startup does not include operation solely for purpo ses of testing equipment. Startup does not include changes in productfor flexible operation units. Storage vessel means a tank or other vessel th at is used to store orga nic liquids. Storage vessel does not include: (1) Vessels permanently attached to motor vehicles such as truc ks, railcars, barges, or ships; (2) Pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere; (3) Vessels with capacities sm aller than 40 cubic meters; (4) Bottoms receiver tanks; orPage 22 of 109

(5) Wastewater storage tanks. Wastewater stor age tanks are covered under 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 m onitored expressed in degrees Celsius or ±0.5 °C, whichever is greater.

Total annual benzene means the total amount of benzene in waste stream s 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 ethane measured according to th e procedures of Method 18 of 40 CFR part 60, appendix A. Method 25A may be used alone or in combination with Me thod 18 to measure TOC as provided in §63.645 of this subpart.

Wastewater means water or wastewater that, during pr oduction or processing, comes into direct contact with or results from the production or use of any raw material, intermediate product, finished product, byproduct, or wa ste product and is discharged in to any individual drain system. Examples are feed tank drawdow n; water formed during a che mical reaction or used as a reactant; water used to wash im purities from organic produ cts or reactants; water used to cool or quench organic vapor streams th rough direct contact; and cond ensed steam from jet ejector systems pulling vacuum on vessels containing organics. § 63.642 General standards. (a) Each owner or operator of a so urce 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 op erating permit program has not been ap proved, the source shall apply to the EPA Regional Office pursuant to part 71. (b) [Reserved] (c) Table 6 of this subpart specifi es the provisions of s ubpart 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 determinat ions shall be required only as specified in this subpart. (1) Performance tests and compliance determin ations shall be conducted according to the schedule and procedures spec ified in this subpart. (2) The owner or operator sh all notify the Administrator of the intention to conduct a performance test at least 30 days befo re the performance test is scheduled.Page 23 of 109

(3) Performance tests shall be conducted accordi ng to the provisions of §63.7(e) except that performance tests shall be condu cted 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 oper ating conditions for monitored control device parameters, whichever results in lower emission reduction. (4) Data shall be reduced in accordance withthe 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 this part. (e) Each owner or operator of a so urce subject to this subpart sha ll keep copies of all applicable reports and records required by this subpart for at least 5 years ex cept as otherwise specified in this subpart. All applicable records shall be mainta ined in such a manner th at 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, microfi lm, computer, floppy disk, magnetic tape, or microfiche. (f) All reports required under this subpart shall be sent to the Administrator at the addresses listed in §63.13 of subpart A of this part. If accep table to both the Administrator and the owner or operator of a source, reports may be submit ted on electronic media. (g) The owner or operator of an existing source su bject to the requirements of this subpart shall control emissions of organic HAP’s to the level represented by the following equation:

E A = 0.02 Σ EPV 1 + Σ EPV 2 + 0.05 Σ 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.

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

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

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

Σ ES 2 = Sum of the emissions, megagr ams per year, from all Group 2 storage vessels, as defined in §63.641.

Σ EGLR 1C = Sum of the residual e missions, megagrams per year, from all Group 1 gasoline loading racks, as defined in §63.641.Page 24 of 109

Σ EGLR 2 = Sum of the emissions, me gagrams per year, from all Gr oup 2 gasoline loading racks, as defined in §63.641. (R) Σ EMV 1 = Sum of the residual em issions megagrams per year, from all Group 1 marine tank vessels, as defined in §63.641. R = 0.03 for existing sources, 0.02 for new sources.

Σ EMV 2 = Sum of the emissions, megagrams per ye ar from all Group 2 mari ne tank vessels, as defined in §63.641.

Σ EWW 1C = Sum of the residual emi ssions from all Group 1 wastewat er 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 wa stewater streams, as defined in §63.641. The emissions level represented by this equati on is dependent on the collection of emission points in the source. The level is not fixed and can change as the emissions from each emission point change or as the nu mber of emission points in the source changes. (h) The owner or operator of a new source subject to the re quirements of this subpart shall control emissions of organic HAP’s to the level represented by the equation in paragraph (g) of this section. (i) The owner or operator of an existing source shall demons trate compliance with the emission standard in paragraph (g) of th is section by following the proced ures specified in paragraph (k) of this section for all emissi on 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 emis sion points 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 proced ures in paragraph (k) of this section. The owner or operator of a new source 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 th e miscellaneous process vent provisions in §§63.643 through 63.645, the storage vessel provisions in §63.646, the wa stewater provisions in §63.647, the gasoline loading rack provisions in §63.650, and the marine tank vessel lo ading operation provisions in §63.651 of this subpart. (1) The owner or operator us ing this compliance approach shall also comply with the requirements of §63.655 as applicable.Page 25 of 109

(2) The owner or operator using this compliance approach is notrequired to calculate the annual emission rate specified in para graph (g) of this section. (l) The owner or operator 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 emissions for the source do not ex ceed the emission level specified in paragraph (g) of this section. The owner or operator using emissions averaging shall meet the requirem ents in paragraphs (l)(1) and (l)(2) of this section. (1) Calculate emission debits a nd credits for those emission poin ts involved in the emissions average according to the proce dures 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 owne r or operator of an ex isting source to usi ng only the procedures in paragraph (k) of this section to comply with the e mission standard in paragraph (g) of this section. Such a restriction w ould preclude the sour ce from using an emissions averaging compliance approach. § 63.643 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 para graphs (a)(1) or (a)(2 ) of this section. (1) Reduce emissions of organic HAP’s using a flare that meets th e requirements of §63.11(b) of subpart A of this part. (2) Reduce emissions of organi c HAP’s, using a control device, by 98 weight-percent or to a concentration of 20 parts per m illion by volume, on a dry basis, corrected to 3 percent oxygen, whichever is less stringent. Compliance can be de termined by measuring either organic HAP’s or TOC’s using the pr ocedures in §63.645. (b) If a boiler or process heater is used to comply with the perc entage of reduction requirement or concentration limit specified inparagraph (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 th at the required percent reduction or concentration is ac hieved. Testing and monitoring is required only as specified in §63.644(a) and §63.645 of this subpart. § 63.644 Monitoring provisions fo r miscellaneous process vents. (a) Except as provided in paragraph (b) of th is section, each owner or operator of a Group 1 miscellaneous process vent that uses a combustio n device to comply with the requirements in §63.643(a) shall install the monitori ng equipment specified in paragr aph (a)(1), (a)(2), (a)(3), or (a)(4) of this section, depend ing on the type of combustion device used. All monitoring equipment shall be installed, ca librated, maintained, a nd operated according to manufacturer’sPage 26 of 109

specifications or other written procedures that provide adequate assurance that the equipment will monitor accurately. (1) Where an incinerator is us ed, a temperature monitoring devi ce equipped with a continuous recorder is required. (i) Where an incinerator other than a catalytic incinerator is used, a temperature monitoring device shall be installe d in the firebox or in the ductwork immediately downstream of the firebox in a position before any substa ntial heat exchange occurs. (ii) Where a catalytic incinerator is used, temper ature monitoring devices sh all be installed in the gas stream immediately before and after the catalyst bed. (2) Where a flare is used, a devi ce (including but not limited to a thermocouple, an ultraviolet beam sensor, or an infrared se nsor) capable of continuously de tecting the pres ence of a pilot flame is required. (3) Any boiler or process heater with a design he at input capacity greater than or equal to 44 megawatt or any boiler or process heater in wh ich all vent streams are introduced into the flame zone is exempt from monitoring. (4) Any boiler or process heater less than 44 me gawatts design heat capacity where the vent stream is not introduced 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 ve nt may request approval to monitor parameters other than those listed in para graph (a) of this section. The request shall be submitted according to the proc edures specified in §63.655(h). Appr oval shall be requested if the owner or operator: (1) Uses a control device other than an incine rator, boiler, process heater, or flare; or (2) Uses one of the control devices listed in para graph (a) of this secti on, 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 eith er paragraph (c)(1) or (c)(2) of this section. Equipment such as low leg drains, high point bleeds , analyzer vents, open-ended valves or lines, pressure relief valves needed for safety reas ons, and equipment subject to §63.648 are not subject to this paragraph. (1) Install, calibrate, maintain, and operate a fl ow indicator that dete rmines whether a vent stream flow is present at leas t once every hour. Records shall be generated as specified in §63.655(h) and (i). The flow indicato r shall be installed at the en trance to any bypass line that could divert the vent stream away from the control device to the atmosphere; orPage 27 of 109

(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 mechanis m shall be performed at least once every month to ensure thatthe valve is maintained in the closed positi on and the vent stream is not diverted through the by pass line. (d) The owner or operat or shall establish a range that en sures compliance with the emissions standard for each parameter monitored under paragra phs (a) and (b) of this section. In order to establish the range, th e 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 th e monitoring provisions of this section shall operate the contro l device in a manner consiste nt 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 perfo rm procedures required by this section shall constitute a viol ation of the applicable emissi on standard of this subpart. § 63.645 Test methods and procedures for miscellaneou s process vents. (a) To demonstrate complian ce with §63.643, an owner or oper ator 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 this 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 th e organic HAP’s in table 2 of subpart F of this part. (d) All references to §63.116(b)(1) or (b)(2) shal l be replaced with paragraphs (d)(1) and (d)(2) of this section, respectively. (1) Any boiler or process heater with a design he at input capacity of 44 megawatts or greater. (2) Any boiler or process heater in which all ve nt streams are introduced into the flame zone. (e) For purposes of determining the TOC emission rate, as specifi ed under paragraph (f) of this section, the sampling site shall be after the last product recove ry device (as defined in §63.641 of this subpart) (if any recovery de vices are present) but prior to the inlet of any control device (as defined in §63.641 of this subpart) that is present, prior to an y 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.Page 28 of 109

(2) No traverse site selection method is needed for vents smaller than0.10 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 th an 33 kilograms per day for an existing source or less than 6.8 kilograms per da y for a new source in accordance with the Group 2 process vent definition of th is subpart shall determine the TO C mass flow rate by the following procedures: (1) The sampling site shall be selected as specified in para graph (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; alternatively, any other method or data that has been validated according to the protocol in Method 301 of appendix A of this part may be us ed. If Method 25A is used, and the TOC mass flow rate calculated fro m 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 following 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 samp ling is used, then the sa mples shall be taken at approximately equal intervals in time, su ch as 15-minute interv als during the run. (ii) The TOC concentration (C TOC ) is the sum of the concentrati ons of the individual components and shall be computed for eac h run using the following equa tion if Method 18 is used:

where:

C TOC = Concentration of TOC (min us methane and ethane), dry basis, parts per million by volume.

C

ji = Concentration of sample component j of the sample i, dry basis, parts per million by volume. n = Number of components in the sample. x = Number of sample s in the sample run.Page 29 of 109

(4) The emission rate of TOC (minus methane and ethane) (E TOC ) shall be calculated using the following equation if Method 18 is used:

where: E = Emission rate of TOC (minus methane a nd ethane) in the sample , kilograms per day.

K2 = Constant, 5.986 × 10 − 5 (parts per million) − 1 (gram-mole per stan dard 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 basi s of organic compound j in part s 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 meas ured minus methane and ethane.

M

j = Molecular weight of organic compound j, gram per gram-mole. Q s = Vent stream flow rate, dry standard 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 = K2 C TOC MQ s where:

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

K2 =Constant, 5.986×10 –5 (parts per million) − 1 (gram-mole per standard cubic meter) (kilogram per gram)(minute per day), where the standard te mperature (standard cubi c meter) is at 20 °C.

C TOC = Concentration of TOC on a dry basis in parts per milli on volume as measured by Method 25A of 40 CFR part 60, appendix A, as indicat ed in paragraph (f)(3 ) of this section. M = Molecular weight of organic co mpound used to express units of C TOC , gram per gram-mole. Q s = Vent stream flow rate, dry standard cubic meters per minute, at a temperature of 20 °C. (g) Engineering assessment ma y be used to determine the TOC emission rate for the representative operating cond ition expected to yield the highest daily emission rate. (1) Engineering assessment includes, but is not l imited to, the following:Page 30 of 109

(i) Previous test results provided the tests are representative of current operating practices at the process unit. (ii) Bench-scale or pilot-scale test data representative of th e process under representative operating 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 properties. Examples of analytical methods include, but are not limited to: (A) Use of material balances based on proc ess stoichiometry to estimate maximum TOC concentrations; (B) Estimation of maximum flow rate based on physical equipment de sign such as pump 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 proces s changes are made to determine whether the vent is in Group 1 or Group 2. Examples of proc ess changes include, but are not limited to, changes in production capacity, production rate, or catalyst type, or whenever there is replacement, removal, or addition of recoveryequipment. For purposes of this paragraph, process changes do not in clude: process upsets; unintentional, temporary process changes; and changes that are within the range on whic h the original calc ulation was based. (1) The TOC emission rate shall be recalculated based on measuremen ts of vent stream flow rate and TOC as specified in paragraphs (e) and ( f) of this section, as applicable, or on best engineering assessment of the effects of the ch ange. Engineering assess ments shall meet the specifications in paragra ph (g) of this section. (2) Where the r ecalculated TOC emission rate is greate r than 33 kilograms per day for an existing source or greater than 6.8 kilograms pe r 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 emissi ons 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 109

§ 63.646 Storage vessel provisions. (a) Each owner or operator of a Group 1 storage vessel subject to this subpart 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, a ll terms not defined in §63.641 shall ha ve the meaning given them in 40 CFR part 63, subparts 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 th e determination shall be documented. (2) When an owner or operat or and the Administrator do no t agree on whether the annual average weight percent organic HAP in the stor ed liquid is above or below 4 percent for a storage vessel at an existing s ource or above or below 2 percen t for a storage vessel at a new source, Method 18 of 40 CFR part 60, appendix 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 (o r the schedule provisions and the compliance date) shall be replaced with §63.640(h), (2) All references to April 22, 1994 sh all 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 comp liance 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 partshall be replaced with §63.652. (6) All references to §63.113(a)(2 ) of subpart G shall be replac ed 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 109

(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 subpart , 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 subpar t G are not applicable. For sources subject to this subpart , such references shall mean that §63.647 of this subpart is applicable. (e) When complying with the in spection requirements of §63.120 of subpart G of this part, owners and operators of storag e vessels at existing sources subject to th is subpart are not required to comply with the provisions for gask ets, 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 insta lled on an opening on a floating roof, the cover or lid shall remain closed except when the cover or lid must be open for access. (2) Rim space vents are to be set to open only wh en the floating roof is not floating or when the pressure beneath the rim seal exceeds the manufacturer’s recommended setting. (3) Automatic bleeder vents are 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 th is section shall constitute a violation of the applicable 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 Implemen tation Plan in §63.120, paragraphs (d)(2) and (d)(3 )(i) shall be replaced with the Notification of Compliance Status report. (j) References to the Notification of Co mpliance 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)(1 0)(ii), and 63.120(b)(10)(iii) for all or some storage vessels at petroleum refineries su bject to this subpart. The State or local pe rmitting authority may also grant permission to refill storage vesse ls sooner than 30 days after submitting the notifications in §§63.120(a)(6) or 63. 120(b)(10)(iii) for all storage ve ssels at a refinery or for individual storage vessel s on a case-by-case basis.Page 33 of 109

§ 63.647 Wastewater provisions. (a) Except as provided in paragraph (b) of th is section, each owner or operator of a Group 1 wastewater stream shall comp ly 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, a ll terms not defined in §63.641 shall ha ve the meaning given them in the Clean Air Act or in 40 CFR part 61, subpart FF, §61.341. (c) Each owner or operator re quired under subpart FF of 40 CFR pa rt 61 to perform periodic measurement of benzene concentration in wastewat er, or to monitor pro cess or control device operating parameters shall operat e in a manner consistent with the minimum or maximum (as appropriate) permitted concentra tion or operating parameter valu es. Operation of the process, treatment unit, or control device resulting in a measured conc entration or operating parameter value outside the perm itted limits shall constitute a violation of the emission standards. Failure to perform required leak monitoring fo r closed vent systems and contro l devices or failure to repair leaks within the time period speci fied in subpart FF of 40 CFR part61 shall constitute a violation of the standard. § 63.648 Equipment leak standards. (a) Each owner or operator of an existing source subjectto the provisions of this subpart shall comply with the provis ions of 40 CFR part 60 subpart VV an d paragraph (b) of this section 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 prov ided in paragraphs (c) through (i) of this section. (1) For purposes of compliance w ith this section, th e provisions of 40 CFR part 60, subpart VV apply only to equipment in or ganic HAP service, as define d in §63.641 of this subpart. (2) Calculation of percentage leaking equipm ent components for subpart VV of 40 CFR part 60 may be done on a process unit basi s or a sourcewide basis. Once the owner or operator has decided, all subsequent calculati ons shall be on the same basis unless a permit change is made. (b) The use of monitoring datagenerated 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 requirements of paragraphs (b)(1 ) and (b)(2) of this section. (1) Monitoring data must meet the test methods and procedures spec ified 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 departures. (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 pa rt or from the monitori ng frequency specified in subpart VV or in paragraph (c) of this secti on (such as every 6 weeks instead of monthly orPage 34 of 109

quarterly) are minor and do not significantly aff ect the quality of the data. An example of a minor departure is monito ring at a slightly different frequenc y (such as every 6 weeks instead of monthly or quarterly). Failure to use a calibrated instrument is notconsidered a minor departure. (c) In lieu of complying with the existing source provisi ons of paragraph (a) in this section, an owner or operator may elect to comply with the requiremen ts 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) thr ough (i) of this section. (1) The instrument readings th at define a leak for light liq uid pumps subject to §63.163 of subpart H of this part and gas/ vapor and light liquid valves s ubject 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 owne r or operator may monitor valves for leaks as specified in paragraphs (c)(2)(i) or (c)(2)(ii) of this section. (i) If the owner or op erator does not elect to monitor connectors, then th e owner or operator shall monitor valves according to the frequency specified in table 8 of this subpart. (ii) If an owner or operator elects to monitor connectors according to the provisions of §63.649, paragraphs (b), (c), or (d), th en the owner or operator shall m onitor 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) wh ether to calculate th e percentage leaking valves on a process unit basis or on a sourcewide basis. Once th e owner or operator has decided, all subsequent calculations sh all be on the same basis unl ess a permit change is made. (4) The owner or operator shall decide no later than the firs t monitoring period after the phase III compliance date specified in §63.640(h) whethe r to monitor connector s according to the provisions in §63.649, paragraphs (b), (c), or (d). (5) Connectors in gas/vapor serv ice or light liquid service are subject to the requirements for connectors in heavy liquid servic e in §63.169 of subpart H of this part (except for the agitator provisions). The leak de finition 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 achieve less than 10 percent of light li quid pumps leaking or three light liquid pumps leaking, whichever is greater, shall monitor light liq uid pumps monthly. (7) Owners or operators that ach ieve less than 3 percent of li ght liquid pumps leaking or one light liquid pump leaking, whiche ver is greater, sha ll monitor light liquid pumps quarterly.Page 35 of 109

(8) An owner or operator may make the election de scribed in paragraphs (c )(3) and (c)(4) of this section at any time except that any election to cha nge after the initial electi on shall be treated as a permit modification accordi ng to the terms of part70 of this chapter. (9) When complying with the re quirements 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. Otherw ise, 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 valv es for subsequent monitoring periods. When the number of non-re pairable valves exceeds 3 perc ent of the total number of valves in organic HAP service, the number of non-repairable valves ex ceeding 3 percent of the total number shall be included in the calculation of percent leaking valves. (10) If in phase III of the valv e standard any valve is designated as being leakless, the owner or operator has the option of following the pr ovisions of 40 CFR 60.482–7(f). If an owner or operator chooses to comply with the provision s 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 operat or shall comply wi th §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 h eavy liquid service and agitators inheavy 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 se rvice are exempt from §§63.163 and 60.482 if recasting the distance piece or reciprocat ing pump replacement is required. (g) Compressors in hydrogen service are exempt fro m the requirements of paragraphs (a) and (c) of this section if an owner or operator demonstrates that a co mpressor is in hydrogen service. (1) Each compressor is pr esumed not to be in hydrogen se rvice unless an owner or operator demonstrates that the piece of eq uipment 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 reasonab ly 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, th e owner or operator shall use either: (A) Procedures that conform to those speci fied in §60.593(b)(2) of 40 part 60, subpart GGG.Page 36 of 109

(B) Engineering judgment to de monstrate that the percentage content exceeds 50 percent by volume, provided the engineeri ng 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 dete rmines that a piece of equipmen t is in hydrogen 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 years. (i) Reciprocating compressors ar e exempt from seal requirements if recasting the distance piece or compressor repl acement is required. § 63.649 Alternative means of emission limitation: Connector s in gas/vapor service and light liquid service. (a) If an owner or operator elects to monitor valves acco rding to the provisions of §63.648(c)(2)(ii), the owner or op erator shall implem ent one of the c onnector monitoring programs specified in paragraphs (b), (c), or (d) of this section. (b) Random 200 connector alternative . The owner or operator shall implement a random sampling program for acce ssible connectors of 2.0 inches no minal diameter or greater. The program does not apply to inaccessible or unsaf e-to-monitor connectors, as defined in §63.174 of subpart H. The sampling program sh all be implemented source-wide. (1) Within the first 12 months after the phas e III compliance date specified in §63.640(h), a sample of 200 connectors shall be randomly sel ected and monitored usin g Method 21 of 40 CFR part 60, appendix A. (2) The instrument readi ng 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 de tected except as provided in paragr aph (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 de tected, the connector shall be monitored for leaks withinthe first 3 months after its repair. (5) After conducting the initial surv ey required in paragraph (b)(1) of this section, the owner or operator shall conduct su bsequent monitoring of connectors at the frequencies specified in paragraphs (b)(5)(i) through (b )(5)(iv) of th is section.Page 37 of 109

(i) If the percentage leaking conn ectors 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 le aking connectors is 1.0 percent or grea ter but less than 2.0 percent, the owner or operator shall survey a random sample of 200 connectors once per year. (iii) If the percentage leaking c onnectors is 0.5 percent or greater but less than 1.0 percent, the owner or operator shall surv ey a random sample of 200 c onnectors once every 2 years. (iv) If the percentage le aking connectors is less than 0.5 perc ent, the owner or operator shall survey a random sample of 200 connectors once ev ery 4 years. (6) Physical tagging of the conn ectors to indicate that they ar e subject to the monitoring provisions is not required . Connectors may be identified by the ar ea or length of pipe and need not be individually identified. (c) Connector inspection alternative . The owner or operator sh all implement a program to monitor all accessible connectors in gas/vapor serv ice that are 2.0 inches (nominal diameter) or greater and inspect all accessible connectors in li ght liquid service that are 2 inches (nominal diameter) or greater as described in paragraphs (c)(1) through (c)(7) of th is section. The program does not apply to inaccessible or unsafe-to-monitor connectors. (1) Within 12 months after the phase III complia nce 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 is 1,000 parts per million. (2) All connectors in light liquid service shall be in spected 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 as soon as practicable, but no later than 15 calendar days after the leak is de tected except as provided in paragr aph (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 detect ed, connectors in gas/vapor service shal l be monitored for leaks within the first 3 months after repair. Connect ors 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 th an three drops per minute. (5) After conducting the initial surv ey required in paragraphs (c)(1) and (c)(2) of this section, the owner or operator shall conduct subsequent monitoring at the frequencies specified in paragraphs (c)(5)(i) through (c)(5)(iii) of this section. (i) If the percentage leaking conn ectors is 2.0 percent or greater, the owner or operator shall monitor or inspect, as applicab le, the connectors once per year.Page 38 of 109

(ii) If the percentage le aking connectors is 1.0 percent or grea ter but less than 2.0 percent, the owner or operator sha ll monitor or inspect, as applicable , the connectors onc e every 2 years. (iii) If the percentage leaking c onnectors is less than 1.0 percent, the owner or operator shall monitor or inspect, as applicable, the connectors once every 4 years. (6) The percentage leaking connectors shall be cal culated for connectors in gas/vapor service and for connectors in light liquid se rvice. The data for the two groups of conn ectors shall not be pooled for the purpose of determining the percenta ge 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 nonrep airable connectors, as dete rmined 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 pro cess unit.

C c = Optional credit for removed connectors= 0.67×net number (i.e., the total number of connectors removed minus the tota l added) of connectors in or ganic HAP service removed from the process unit after th e applicability date set forth in §63.640(h)(4)(iii) for existing process units, and after the date of st art-up for new process units. If credits are not taken, then C c = 0. (ii) Nonrepairable connectors sh all be included in the calcu lation of percentage leaking connectors the first time the connector is identifi ed as leaking and nonre pairable. Otherwise, a number of nonrepairable connector s 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 connect ors for subsequent monitoring periods. (iii) If the number of nonrep airable connectors exceeds 3 perc ent of the total number of connectors in organic HAP servic e, the number of nonrepairable connectors exceeding 3 percent of the total number shall be included in the calculation of the percenta ge leaking connectors. (7) Physical tagging of the conn ectors to indicate that they ar e subject to the monitoring provisions is not required . Connectors may be identified by the ar ea or length of pipe and need not be individually identified.Page 39 of 109

(d) Subpart H program . The owner or operator shall implement a program to comply with the provisions in §63.174 of this part. (e) Delay of repair of co nnectors for which leaks have been det ected is allowed if repair is not technically feasible by normal re pair techniques without a proce ss unit shutdown. Repair of this equipment shall occur by the end of the next process unit shutdown. (1) Delay of repair is allowed fo r equipment that is is olated from the proc ess and that does not remain in organic HAP service. (2) Delay of repair for conn ectors is also allowed if: (i) The owner or operator dete rmines that emissions of purge d 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 accomplished, the purged material w ould 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 determ ines that repair personnel woul d be exposed to an immediate danger as a consequence of comp lying with paragraphs (b)(3) a nd (b)(4), (c)(3) and (c)(4), of this section; or (2) The connector will be repaired before the end of the next scheduled process unit shutdown. (g) The owner or operator shall maintain records to documen t that the connector monitoring or inspections have been conducted as required and to document re pair of leaking connectors as applicable. § 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 cl assified under Standard Indu strial Classification code 2911 located within a contig uous 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, a ll terms not defined in §63.641 shall ha ve the meaning given them in subpart A or in 40 CFR part 63, subpart R. Th e §63.641 definition of “affected source” applies under this section. (c) Gasoline loading racks regul ated under this subpa rt are subject to the compliance dates specified in §63.640(h).Page 40 of 109

§ 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 tank vessel loading operati on located at a petroleum refi nery shall comply with the requirements of §§63.560 through 63.568. (b) As used in this section, a ll terms not defined in §63.641 shall ha ve the meaning given them in subpart A or in 40 CFR part 63, subpart Y. Th e §63.641 definition of “affected source” applies under this section. (c) The notification reports und er §63.567(b) are not required. (d) The compliance time of 4 ye ars after promulgation of 40 CF R part 63, subpart Y does not apply. The compliance time is specified in§63.640(h)(3). § 63.652 Emissions averaging provisions. (a) This section applies to owners or operators of existing source s who seek to comply with the emission standard in §63.642(g) by using emis sions averaging according to §63.642(l) rather than following the provis ions of §§63.643 through 63.647, and §§63.650 and 63.651. Existing marine tank vessel loading operati ons located at the Valdez Mari ne Terminal source may not comply with the standard by using emissions averaging. (b) The owner or operator sh all develop and submit for appr oval an Implementation Plan containing all of the in formation required in §63.653(d) for all points to be included in an emissions average. The Implementation Plan shall id entify all emission points to be included in the emissions average. This mu st 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 emission poi nts can be used to generate emi ssions averaging credits if control was applied after November 15, 1990 and if sufficient information is available to determine the appropriate value of cred its for the emission point: (1) Group 2 emission points; (2) Group 1 storage vessels, Group 1 wastewater streams, Group 1 gasolin e loading racks, Group 1 marine tank vessels, and Group 1 miscellane ous process vents thatare controlled by a technology that the Administrator or permitting authority agrees ha s a higher nominal efficiency than the reference control technology. Inform ation on the nominal ef ficiencies for such technologies must be submitted a nd approved as provided in paragr aph (i) of this section; and (3) Emission points from wh ich emissions are reduced by pollution prevention measures. Percentages of reduction for pollu tion prevention measures shall be determined as specified in paragraph (j) of this section.Page 41 of 109

(i) For a Group 1 emission point, the pollution prevention measure must reduce emissions more than the reference control tec hnology would have had the refe rence control technology been applied to the emission point in stead of the pollution prevention measure except as provided in paragraph (c)(3)(ii) of this section. (ii) If a pollution prevention meas ure is used in conjunction w ith other controls for a Group 1 emission point, the pollution prevention measure alone does not ha ve to reduce emissions more than the reference control tec hnology, but the combination of the pollution prevention measure and other controls must reduce em issions more than the referenc e control technology would have had it been applied instead. (d) The following emissi on points cannot be used to genera te emissions averaging credits: (1) Emission points already co ntrolled on or before Novemb er 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 af ter November 15, 1990; (2) Group 1 emission points that are controlled by a reference control technology 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 allowabl e to claim that an internal floating roof meeting only the specifications stated in the refe rence control technology definiti on 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. Proc ess units that are shut down cannot be used to generate credits or debits; (4) Wastewater that is not process wastewater or wastewater stream s 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 uncon trolled to generate debits. For the purposes of this secti on, the terms “wastewater” and “w astewater 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 November 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 cred ited. However, if an emission point ha s been used to generate emissions averaging credit in an approved emissions average, and the point is subsequently made subject to a State or Federal rule other th an this subpart, the point can c ontinue to generate emissions averaging credit for the purpose of complying with the prev iously approved average. (e) For all points included in an emissions average, the owner or operator shall:Page 42 of 109

(1) Calculate and record monthly debits for all Group 1 emission poi nts that are controlled to a level less stringent than the re ference control technology for thos e 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 th e debits. Equations in paragraph (h) of this section shall be used to calculate credits. Emission points and controls that m eet the criteria of paragraph (c) of this section may be included in the credit calculation, whereas t hose described in paragraph (d) of this section shall not be included. (3) Demonstrate that annual cred its calculated according to para graph (h) of this section are greater than or equal to deb its calculated for the same annu al compliance period according to paragraph (g) of this section. (i) The initial demonstration in the Implementation Plan that credit-generati ng emission points will be capable of generating suff icient credits to offset the debits from the debit-generating emission points must be ma de under representative operating conditions. (ii) After the compliance date, actual operating data will be us ed for all debit and credit calculations. (4) Demonstrate that debits calculated for a qu arterly (3-month) period according to paragraph (g) of this section are not mo re than 1.30 times th e credits for the same period calculated according to paragraph (h) of this section. Compli ance for the quarter shall be determined based on the ratio of credits and debits from that quar ter, with 30 percent more debits than credits allowed on a quarterly basis. (5) Record and report quarterly a nd annual credits and debits in th e Periodic Reports as specified in §63.655(g)(8). Every fourth Peri odic Report shall incl ude a certification of compliance with the emissions averaging provision s as required by §63.655(g)(8)(iii). (f) Debits and credits shall be calculated in accordance withthe methods and procedures specified in paragraphs (g) and (h ) of this section, respectively, and shall not in clude emissions from the following: (1) More than 20 individual em ission points. Where pollution pr evention measures (as specified in paragraph (j)(1) of this sect ion) are used to control emissi on 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 point s 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, an d 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 109

(3) For emission points for which continuous monitors are used, pe riods of excess emissions as defined in §63.655(g)(6)(i). For thes e periods, the calculation of m onthly credits and debits shall be adjusted as specified in paragraphs (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 us e the procedures in paragraph (l) of this section to demonstrate to the Administrator that full or partial credits or debits s hould be assigned. (g) Debits are generated by the difference betw een the actual emissions from a Group 1 emission point that is uncontrolle d or is controlled to a level less stringent than the reference control technology, and the emissions allowed for Group 1 emis sion point. Debits shall be calculated as follows: (1) The overall equation for calcu lating sourcewide debits is:

where: Debits and all terms of the equation ar e 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 stri ngent 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 miscellane ous process vent i if the reference control technology had been applied to the un controlled emissions, calculated according to paragraph (g)(2) of this section.

ES iACTUAL = Emissions from each Group 1 st orage vessel i that is uncontrolled or is controlled to a level less stringent than the reference co ntrol technology. 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 uncontrol led emissions, calculated accordi ng to paragraph (g)(3) of this section.Page 44 of 109

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

EGLR ic = Emissions from each Gro up 1 gasoline loadi ng rack i if the reference control technology had been applied to the uncontrolle d emissions. This is calculated according to paragraph (g)(4) of this section.

EMV ACTUAL = Emissions from each Group 1 marine tank ve ssel i that is uncontrolled or is controlled to a level less stri ngent than the refere nce control technology. This is calculated according to paragraph (g)(5) of this section. (0.03) EMV iu= Emissions from each Group 1 marine ta nk vessel i if the reference control technology had been applied to the uncontrolled emissions calcu lated 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 for 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 fl ow rate, organic HAP concentrations, and temperature, the sampling site shall be af ter the final product recovery device, if any recovery devices are present; before any control device (for miscellaneous process vents, recovery devices shall no t be considered control devices) ; and before discharge to the atmosphere. Method 1 or 1A of part 60, appendix A shall be used for se lection of the sampling site. (ii) The following equa tion shall be used for each miscella neous 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 cubi c meters per minute, measured using Methods 2, 2A, 2C, or 2D of part 60 ap pendix A, as appropriate. h = Monthly hours of operation during which pos itive flow is present in the vent, hours per month.Page 45 of 109

C

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

M

j = Molecular weight of 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 pe rformance test conducted under representative operating cond itions. The values of Q, C j , and M j shall be established in the Notification of Compliance Status report a nd 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 m onthly operating hours, or if any other change is made to the process or product recovery eq uipment or operation such that the previously measur ed values of Q, C j , and M j are no longer representa tive, 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 procedur es and equations shall be used to calculate EPV iACTUAL : (A) If the vent is not controlle d by a control device or pollution prevention measure, EPV iACTUAL = EPV iu , where EPV iu is calculated according to the proced ures in paragraphs (g)(2)(i) and (g)(2)(ii) of this section. (B) If the vent is controlled us ing a control device or a polluti on 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 meet ing the criteria in §6 3.116(a) of subpart G, or a boiler or process heater m eeting the criteria in §63.645(d) of this subpart or §63.116(b) of subpart G, the percentage of reduction shall be 98 percent. If a noncombus tion control device is used, percentage of reduction sha ll be demonstrated by a performan ce test at the inlet and outlet of the device, or, if testing is not feasible, by a control de sign evaluation and documented engineering calculations. ( 2 ) For determining debits from miscellaneous pro cess vents, product reco very devices shall not be considered control devices a nd cannot be assigned a percentage of reduction in calculating EPV iACTUAL . The sampling site for measurement of un controlled emissions is after the final product recovery device.Page 46 of 109

( 3 ) Procedures for calculating the percentage of reduction of pollution pr evention measures are specified in paragraph (j) of this section. (3) Emissions from storage vessels shall be calculated as specifiedin §63.150(g)(3) of subpart G. (4) Emissions from gasoline loading rack s shall be calculated as follows: (i) The following equation shall be used for each gasoline load ing 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, dimensionles s (see table 33 of subpart G). P = Weighted 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 atthe gasoline loading rack during the month, gram per gram-mole. G = Monthly volume of gasoline transferred from gasoline loading rack, liters per month. T = Weighted rack bulk liquid lo ading temperature du ring the month, degrees kelvin (degrees Celsius °C + 273). (ii) The following equa tion 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 transf erred at the rack, kilopascals. G = Monthly volume of organic HAP transferred, liters per month, andPage 47 of 109

G

j = Monthly volume of individual organic HAP transferred at th e gasoline loading rack, liters per month. n = Number of organic HAP’s transf erred at the gasoline loading rack. (iii) The following equation shal l be used for each gasoline load ing rack i to calculate the weighted average rack molecular weight:

where:

M

j = Molecular weight of individu al organic HAP transferred at the rack, gram per gram-mole. G, G j , and n are as defined in paragr aph (g)(4)(ii) of this section. (iv) The following equation shall be used for each ga soline loading rack i to calculate the monthly weighted rack bulk liquid loading temperature:

T

j = Average annual bulk temperat ure of individual organic HAP loaded at the gasoline loading rack, kelvin (degrees Celsius °C+273). G, G j , and n are as defined in paragr aph (g)(4)(ii) of this section. (v) The following equation shall be used to calculate EGLR ic :

G is as defined in paragra ph (g)(4)(ii) of this section. (vi) The following procedures and equati ons shall be used to calculate EGLR iACTUAL : (A) If the gasoline loading ra ck is not controlled, EGLR iACTUAL = EGLR iu , where EGLR iuis calculated using the equations specifi ed in paragraphs (g)(4)(i) thr ough (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 requirement of less th an 10 milligrams of TOC per liter of gasoline loaded,Page 48 of 109

( 1 ) The percent reduction for a control device shall be measured according to the procedures 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 accordi ng 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. (5) Emissions from marine tank vessel lo ading shall be calculated as follows: (i) The following equation sha ll be used for each marine ta nk vessel i to calculate EMV iu :

where:

EMV iu= Uncontrolled marine tank vessel HAP em ission rate from mari ne tank vessel i, megagrams per month. Q i = Quantity of commodity loaded (per vessel type), liters.

F i = Emission factor, megagrams per liter.

P i = Percent HAP.

m = Number of combinations of co mmodities and vesse l types loaded.

Emission factors shall be based on test data or emi ssion estimation procedures specified in §63.565(l) of subpart Y. (ii) The following procedures and equations sha ll be used to calculate EMV iACTUAL : (A) If the marine tank vesse l is not controlled, EMV iACTUAL = EMV iu , where EMV iuis calculated using the equations specified in paragraph (g)( 5)(i) of this section. (B) If the marine tank vessel is controlled us ing a control device or a pollution prevention measure achieving less than 97-percent reduction,Page 49 of 109

( 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 accordi ng 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 betw een emissions that are allowed for each Group 1 and Group 2 emission point and the actual emi ssions 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. Credit s shall be calculated as follows: (1) The overall equation for calcu lating sourcewide credits is:

where: Credits and all terms of the equation are in units of megagrams pe r month, the baseline date is November 15, 1990, and

D = Discount factor = 0.9 for all credit-generating emission poin ts except those controlled by a pollution prevention measure, which will not be discounted.

EPV1 iACTUAL = Emissions for each Group 1 miscellaneous pr ocess vent i that is controlled to a level more stringent than the reference control technology, calc ulated according to paragraph (h)(2) of this section. (0.02) EPV1 iu= Emissions from each Group 1 miscellaneou s process vent i if the reference control technology had been applied to the uncontrolled emissions. EPV1 iuis calculated according to paragraph (h)(2) of this section.Page 50 of 109

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

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

ES1 iACTUAL = Emissions from each Group 1 st orage vessel i that is c ontrolled to a level more stringent than the reference cont rol 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 technology had been applied to the uncontrolled emissions. ES1 iuis calculated accordi ng to paragraph (h)(3) of this section.

ES2 iACTUAL = Emissions from each Group 2 storage vess el 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 ba seline date, as calculated in paragraph (h)(3) of this section.

EGLR1 iACTUAL = Emissions from each Group 1 gasoline loading rack i th at is controlled to a level more stringent than the reference control technology, calc ulated according to paragraph (h)(4) of this section.

EGLR ic = Emissions from each Gro up 1 gasoline loadi ng rack i if the reference control technology had been applied to the uncontrolled emissions. EGLR iuis calculated according to paragraph (h)(4) of this section.

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

EGLR2 iBASE = Emissions from each Group 2 gasoline loading rack i at the 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 tec hnology, calculated according to paragraph (h)(4) of this section. (0.03)EMV1 iu= Emissions from each Group 1 marine ta nk vessel i if the reference control technology had been applied to the uncontrolled emissions. EMV1 iuis 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 109

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 tec hnology, calculated according to paragraph (h)(6) of this section.

EWW1 ic = Emissions from each Group 1 wastewater stream i if th e reference control technology had been applied to the uncontrol led emissions, calculated accordi ng to paragraph (h)(6) of this section.

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

EWW2 iBASE = Emissions from each Group 2 wastewater stream i at th e baseline date, calculated according to paragraph (h)(6) of this section. n = Number of Group 1 emission point s included in the em issions average. The value of n is not necessarily the same for each kind of emission point. m = Number of Group 2 emission points included in the emissions averag e. The value of m is not necessarily the same for each kind of emission point. (i) For an emission point contro lled using a reference control technology, the percentage of reduction for calculating credits shall be no greater than the nomi nal efficiency associated with the reference control technology, unles s a higher nominal efficiency is assigned as specified in paragraph (h)(1)(ii) of this section. (ii) For an emission point cont rolled to a level more string ent than the reference control technology, the nominal efficiency for calculating credits shall be assigned as described in paragraph (i) of this section. A reference control technology may be approved for use in a different manner and assigned a higher nominal effici ency according to the procedures in paragraph (i) of this section. (iii) For an emission point c ontrolled using a pollution prev ention measure, the nominal efficiency for calculating credits shall be determined as describe d in paragraph (j) of this section. (2) Emissions from process vents sh all be determined as follows: (i) Uncontrolled emissions from miscellaneous process vents, EPV1 iu , shall be calculated according to the procedures and equation for EPV iuin paragraphs (g)(2)(i) and (g)(2)(ii) of this section. (ii) Actual emissions from miscellaneous proc ess vents controlled us ing a technology with an approved nominal efficiency greater than 98 pe rcent or a pollution prev ention measure achievingPage 52 of 109

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

(iii) The following proce dures shall be used to calculate actual emissions from Group 2 process vents, EPV2 iACTUAL : (A) For a Group 2 process vent co ntrolled by a control device, a recovery device applied as a pollution prevention project, or a pollution prevention measure, if the control achieves a percentage of reduction less than or equal to a 98 pe rcent reduction,

( 1 ) EPV2 iushall be calculated according to th e equations and procedures for EPV iuin 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 calculate d 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 pa rt of a pollution pr evention project, EPV2 iushall be calculated prior to that recove ry device. The equation for EPV iuin 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 adde d as part of a pollution preven tion 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 approved nominal efficiency greater than a 98 percent or a pollution preventi on measure achieving greater than 98 percent reduction,

(iv) Emissions from Group 2 proc ess vents at baseline, EPV2 iBASE , shall be calculated as follows: (A) If the process vent was unc ontrolled on November 15, 1990, EPV2 iBASE = EPV2 iu , and shall be calculated according to the pr ocedures and equation for EPV iuin paragraphs (g)(2)(i) and (g)(2)(ii) of this section.Page 53 of 109

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

where EPV2 iuis calculated according to the procedures and equation for EPV iuin paragraphs (g)(2)(i) and (g)(2)(ii) of this s ection. The percentage of reduc tion 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 to a process vent as part of a pollution prevention project initiated after November 15, 1990, EPV2 iBASE = EPV2 iu , where EPV2 iuis calculated according to paragraph (h)(2)(iii)(A)( 3 ) of this section. (3) Emissions from storage vessels shall be dete rmined 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 sh all 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) exce pt for §63.119(d)(2). (4) Emissions from gasoline loading rack s shall be determined as follows: (i) Uncontrolled emissi ons from Group 1 gasoline loading racks, EGLR1 iu , shall be calculated according to the procedures and equations for EGLR iuas described in paragraphs (g)(4)(i) through (g)(4)(iv) of this section. (ii) Emissions from Group 1 gasolin e loading racks if the referenc e control technology had been applied, EGLR ic , shall be calculated according to the pr ocedures and equations in paragraph (g)(4)(v) of this section. (iii) Actual emissions from Group 1 gasoline load ing racks controlled to less than 10 milligrams of TOC per liter of gasoline loaded; EGLR iACTUAL , shall be calculated acco rding to the following equation:

(iv) The following procedures sh all be used to calculate actu al emissions from Group 2 gasoline loading racks, EGLR2 iACTUAL :Page 54 of 109

(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 th an the 10 milligrams of TOC per liter of gasoline loaded requirement,

( 1 ) EGLR2 iu shall be calculated according to the equations and procedures for EGLR iuin paragraphs (g)(4)(i) through (g )(4)(iv) of th is section. ( 2 ) The percentage of reduction shall be calculate d 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 rack s at baseline, EGLR2 iBASE , shall be calculated as follows: (A) If the gasoline loading rack was uncontrol led on November 15, 1990, EGLR2 iBASE = EGLR2 iu , and shall be calculated according to the procedures and equations for EGLR iuin paragraphs (g)(4)(i) through (g )(4)(iv) of th is section. (B) If the gasoline loading rack was contro lled on November 15, 1990,

where EGLR2 iuis calculated according to the procedures and equations for EGLR iuin paragraphs (g)(4)(i) through (g)(4)(i v) of this section. Percentage of reduction shall be calculated according to the procedures inparagraphs (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 emis sions from Group 1 marine tank vessels, EMV1 iu , shall be calculated according to the procedures and equations for EMV iuas 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, EMV iACTUAL , shall be calculated accordi ng to the following equation:Page 55 of 109

(iii) The following proce dures shall be used to calculate actual emissions from Group 2 marine tank vessels, EMV2 iACTUAL : (A) For a Group 2 marine tank vess el controlled by a control de vice or a pollution prevention measure achieving a percentage of reduction less than or equal to 97 percent reduction,

( 1 ) EMV2 iushall be calculated acco rding to the equations and procedures for EMV iuin paragraph (g)(5)(i) of this section. ( 2 ) The percentage of reduction shall be calculate d according to the procedures in paragraphs (g)(5)(ii)(B)( 1 ) and (g)(5)(ii)(B)( 2 ) of this section. (B) For a Group 2 marine tank ve ssel controlled using a tech nology or a pollution prevention measure with an approved nominal e fficiency 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 term inal was uncontrolled on November 15, 1990, EMV2 iBASE equals EMV2 iu , and shall be calculated according to the procedures and equations for EMV iuin paragraph (g)(5)(i) of this section. (B) If the marine tank vessel wa s controlled on November 15, 1990,

where EMV2 iuis calculated according to the procedures and equations for EMV iuin paragraph (g)(5)(i) of this section. Percentage of reduction shall be calculat ed according to the procedures in paragraphs (g)(5)(ii)(B)( 1 ) and (g)(5)(ii)(B)( 2 ) of this section. (6) Emissions from wastewater sha ll be determined as follows: (i) For purposes of paragraphs (h)(4)(ii) through (h)(4)(vi) of this secti on, 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 109

(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 waste manage ment 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 biological treatment units. (C) Vapor control device means the control device that receives emissions vented from a treatment process or treatment processes. (ii) The following equa tion shall be used for each wastew ater stream i to calculate EWW ic :

where:

EWW ic = Monthly wastewater stream emission rate if wastewater stream i were controlled by the reference control techno logy, megagrams per month. Q i = Average flow rate for wastewater stream i, liters per minute.

H i = Number of hours during the month that wa stewater stream i was generated, hours per month.

Frm=Fraction removed of organic HAP m in wa stewater, from table 7 of this subpart, dimensionless.

Fe m=Fraction emitted of organic HAP m in wa stewater from table 7 of this subpart, dimensionless. s = Total number of organic HAP’s in wastewater stream i.

HAP im= Average concentration of or ganic HAP m in wastewater stream i, parts per million by weight. (A) HAP imshall be determined for the point of ge neration or at a loca tion downstream of the point of generation. Wastewater samples shall be collected using the sampling procedures specified in Method 25D of 40 CF R part 60, appendix A. Where fe asible, samples shall be taken from an enclosed pipe prior to the wastewater being exposed to the atmosphere. When sampling from an enclosed pipe is not feasible, a mini mum of three representative samples shall be collected in a manner to minimi ze exposure of the sample to the atmosphere and loss of organic HAP’s prior to sampling. The samples collected may be analyzed by eith er of the following procedures:Page 57 of 109

( 1 ) A test method or results from a test method that measures orga nic HAP concentrations in the wastewater, and that has been va lidated pursuant to section 5. 1 or 5.3 of Met hod 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 stre am i, and then HAP immay be calculated using the following equation: HAP im= C im/Fm m , where Fm mfor organic HAP m is obtained from table 7 of this subpart. (B) Values for Q i , HAP im , and C imshall be determined during a performance test conducted under representative conditions. The average value ob tained from three test runs shall be used. The values of Q i , HAP im , and C imshall be established in the No tification 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 operatio n such that the previous ly measured values of Q i , HAP im , and C imare no longer representative, a new pe rformance test shall be conducted to determine new representative values of Q i , HAP im , and C im . These new values shall be used to calculate debits and credits fromthe time of the change forwar d, and the new values shall be reported in the next Periodic Report. (iii) The following equations sh all be used to calculate EWW1 iACTUAL for each Group 1 wastewater stream i that is corr ectly suppressed and is treated to a level more stringent than the reference control technology. (A) If the Group 1 wastewater str eam i is controlled using a treatment pro cess or series of treatment processes with an appr oved nominal reduction efficiency for an individually speciated HAP that is greater than that sp ecified in table 7 of this subpart, and the vapor control device achieves a percentage of redu ction equal to 95 percent, the following equation shall be used:

Where:

EWW iACTUAL = Monthly wastewater stream emission rate if wastewaterstream i is treated to a level more stringent than the referenc e control technology, megagrams per month.

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

Where:Page 58 of 109

HAP im-in= Average concentration of organic HAP m, parts per million by we ight, as defined and determined according to paragra ph (h)(6)(ii)(A) of this section, in the wastewater entering the first treatment process in the series.

HAP im-out = Average concentration of organic HAP m, parts per million byweight, as defined and determined according to paragr aph (h)(6)(ii)(A) of this section, in the wastewater exiting the last treatment process in the 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 appr oved nominal reduction efficiency for an individually speciated HAP that is greater than that speci fied 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 re duction efficiency of the vapor control device, dimensionless, as determined according to the procedures in §63.652(i).

A m= The efficiency of the treatme nt process, or series of tr eatment processes, that treat wastewater stream i in redu cing 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 m eeting the specifications inthe definition of refe rence control technology for wastewater is used, A mshall 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 redu ction must be determined using the equation and methods specifie d in paragraph (h)(6)(iii)(A) of this section for determining PR im . If the value of PR imis greater than or equal to the value of Fr mgiven in table 7 of this subpart, then A mequals Fr munless a higher nominal efficiencyhas been approv ed. If a higher nominal efficiency has been appr oved for the treatment process, the owner or operator shall determine EWW1 iACTUAL according to paragraph (h)(6)(iii)(B) of this section rather than paragraph (h)(6)(iii)(A) of this section. If PR imis less than the value of FR mgiven in table 7 of this subpart, emissions averaging shall not be used for th is emission point. (C) If the Group 1 wastewat er stream i is contro lled using a treatment process or series of treatment processes with an appr oved nominal reduction efficiency for an individually speciated hazardous air pollutant that is greater than that sp ecified in table 7 of this subpart, and the vaporPage 59 of 109

control device has an approved nominal effi ciency 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 shal l be used to calculate EWW2 iBASE for each Group 2 wastewater stream i that on November 15, 1990 was not corr ectly suppressed or was correctly suppressed but not treated:

Where:

EWW2 iBASE = Monthly wastewater stream emission rate if wastewaterstream i is not correctly suppressed, megagrams per month. Q i , H i , s, Fe m , and HAP imare as defined and determined acc ording 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 control methods being used on November 15, 1990 are in place a nd any control methods applied after November 15, 1990 are ignored. However, values for th e parameters in the equation shall be representative of present pro duction levels and stream properties.

where R i is calculated according to para graph (h)(6)(vii) of this sec tion 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 stream s 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 cont rol methods in place accounted for. (vii) The reduction efficiency, R i , of the vapor control device sh all be demonstrated according to the following procedures: (A) Sampling sites shall be sel ected using Method 1 or 1A of 40 CFR part 60, appendix A, as appropriate.Page 60 of 109

(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 sh all not be less than 3 hours duri ng which at least three runs are conducted. ( 2 ) A run shall consist of a 1-hour pe riod 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 control 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 entering and exiting the control device during each run shall be calculated as follows:

Where:

E a= Mass flow rate of organic compounds exit ing the control device , kilograms per hour.

E b = Mass flow rate of organic compounds ente ring 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 = Average volumetric flow rate of vent stream en tering the control devi ce 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 during run p as dete rmined by Method 18 of 40 CFR part 60 appendix A, parts per million by volume on a dry basis.Page 61 of 109

C bip = Concentration of organic compound i measured in the ventstream entering the control device during run p as dete rmined 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 inthe vent stream, kilograms per kilogrammole. n = Number of organic compounds in the vent stream.

0.0416 = Conversion factor for molar volume, kilograms-mole per cu bic meter at 293 kelvin and 760 millimeters mercury absolute. (C) The organic reduction effici ency for the control device sh all be calculated as follows:

Where: R = Total organic reducti on efficiency for the control device, percentage.

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

E a= Mass flow rate of organic compounds exit ing the control device , kilograms per hour. (i) The following procedures sha ll be followed to establish nomina l efficiencies. The procedures in paragraphs (i)(1) through (i)( 6) of this section shall be foll owed for control technologies that are different in use or design from the reference control tech nologies and achieve greater percentages of reduction than th e percentages of efficiency assigned to the reference control technologies in §63.641. (1) In those cases where the owne r or operator is seeking permissi on to take credit for use of a control technology that is differ ent 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 sub mit the information specified inparagraphs (i)(1)(i) through (i)(1)(iv) of this section to the Administrator in writing: (i) Emission stream characteristi cs of each emission point to whic h the control technology is or will be applied including the kind of emission point, flow, organic HAP concentration, and all other stream characteristics necessary to de sign the control technology or determine its performance; (ii) Description of the control technology includ ing design specifications;Page 62 of 109

(iii) Documentation demonstrating to the Administr ator’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 it is infeasible to obtain test data, do cumentation may include a design evaluation and calculations. The engineering basi s of the calculation procedures and all inputs and assumptions made in the calculations shall be documented; and (iv) A description of th e parameter or parameters to be m onitored 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 paragr aph (i)(1) of this section. (3) The Administrator shall determine within 12 0 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 judgmen t, the control technol ogy achieves a level of emission reduction greater than the reference cont rol technology for a particular kind of emission point, the Administrator will publish a Federal Regi ster notice establishi ng a nominal efficiency for the control technology. (4) The Administrator may grant conditional permission to take em ission credits for use of the control technology on requirements that may be n ecessary to ensure operation and maintenance to achieve the specified nominal efficiency. (5) In those cases where the owne r or operator is seeking permissi on to take credit for use of a control technology that is differ ent 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 site, the informati on listed in paragraphs (i)(1)(i) thr ough (i)(1)(iv) of th is section can be submitted to the permitti ng authority for the source for approv al instead of the Administrator. (i) In these instances, use and conditions for use of the contro l technology can be approved by the permitting authority. The perm itting authority shall follow the procedures specified in paragraphs (i)(2) through (i)(4) of this section except that, in thes e instances, a Federal Register notice is not required to esta blish the nominal efficiency for the different technology. (ii) If, in reviewing the subm ittal, the permitting authority be lieves the control technology has broad applicability for use by othe r sources, the permitt ing authority shall s ubmit 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 the permitting authority’s approval of the nom inal efficiency of the control technol ogy for the specific application.Page 63 of 109

(6) If, in reviewing an appl ication for a control technol ogy for an emission point, the Administrator or permitti ng authority determines the control te chnology 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 sh all be used for calculating the efficiency (percentage of reduction) of pollution prevention measures: (1) A pollution prevention measure is any practice that meets the cr iteria of paragraphs (j)(1)(i) and (j)(1)(ii) of this section. (i) A pollution prevention measure is any practice th at results in a lesser quantity of organic HAP emissions per unit of product released to the a tmosphere prior to out-of-process recycling, treatment, or control of emissions while the same product is produced. (ii) Pollution prevention measures may includ e: Substitution of feedstocks that reduce HAP emissions, alterations to the produ ction process to reduce the volum e of materials released to the environment, equipment modifications; housekeep ing measures, and in-p rocess recycling that returns waste materials directlyto production as raw materials. Production cutbacks do not qualify as pollution prevention. (2) The emission reducti on efficiency of pollution preventi on measures implemented after November 15, 1990 can be used in calculating the actual emissions from an emission point in the debit and credit equations in paragraphs (g) and (h) of this section. (i) For pollution preventi on measures, the percentage of redu ction used in the equations in paragraphs (g)(2) and (g)(3) of th is section and paragraphs (h)(2) through (h)(4) of this section is the difference in per centage between the monthly organi c HAP emissions for each emission point after the pollution preventi on measure for the most recent month versus m onthly emissions from the same emission point befo re the pollution prevention meas ure, adjusted by the volume of product produced during the two monthly periods. (ii) The following equati on shall be used to calculate the pe rcentage of reduc tion of a pollution prevention measure fo r each emission point.

Where: Percent reduction = Efficiency of pollution prevention measur e (percentage of organic HAP reduction).Page 64 of 109

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

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

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

P pp = Monthly production after the pollution pr evention measure, 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 equa tions and procedures in paragraphs (g)(2), (g)(3), (g)(4), and (g)(5) of this section for miscellaneous process ve nts, storage vessels, gaso line 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 th at wastewater stream i was di scharged before the pollution 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 wa stewater from table 7 of this subpart, dimensionless.

HAP Bim= Average concentration of organic HAP m in wastewater 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 prev ention measure was implemented prio r to July 14, 1994, records may be used to determine E B .Page 65 of 109

(D) The monthly emissions after th e pollution prevention measure, E pp , may be determined during a performance test or by a design evaluation and docume nted engineering calculations. Once an emissions-to-production ra tio has been established, the ra tio can be used to estimate monthly emissions from m onthly 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 determin ed as described in paragraph (j)(2)(ii)(B) of this section except that Q ppi , H ppi , and HAP ppimshall be determined after the pollution prevention measure has been implemented. (iii) All equations, calculations, test procedures, test results, and other information used to determine the percentage of reduction achiev ed by a pollution prev ention 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 percen tage of reduction in emissions for each emission point must be calculated. (v) For the purposes of the equa tions in paragraphs (h)(2) through (h)(6) of this section used to calculate credits for emission poi nts controlled more stringentl y than the reference control technology, the nominal efficiencyof a pollution prev ention measure is e quivalent to the percentage of reduction of the pollution prev ention measure. When a pollution prevention measure is used, the owner or op erator of a source is not require d to apply to the Administrator for a nominal efficiency a nd is not subject to paragr aph (i) of this section. (k) The owner or operator sh all demonstrate that the emi ssions 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 authorit y, greater risk to human health or the environment 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 authority. (i) The State or local permitting authority may require owners and operators to use specific methodologies and procedures for maki ng a hazard or risk determination. (ii) The demonstration and approval of hazard or risk equivalency may be made according to any guidance that the EPA makes available for use.Page 66 of 109

(2) Owners and operator s shall provide documentation dem onstrating the hazard or risk equivalency of their propos ed emissions average in their Implementation Plan. (3) An emissions averaging plan th at does not demonstrate an equiva lent or lower hazard or risk to the satisfaction of the State or local permitting authority sha ll not be approve d. The State or local permitting authority may requ ire such adjustments to the emissions averaging plan as are necessary 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 or risk equi valency demonstration shall: (i) Be a quantitative, bona fide ch emical 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 local permitting aut hority for such demonstrations. (l) For periods of excess emissi ons, an owner or operator may re quest 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 operat or 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 calculations are appropriate to establish that the control devi ce for the emission point was operating in such a fashion to warrant assign ing full or partial cred its and debits. This demonstration shall be made to the Administrator’s satisfact ion, and the Administrator may establish procedures for demonstra ting compliance that are acceptable. (3) The owner or operator shall provide documentation of th e period of excess emissions and the other type of monitoring data orengineering calculations to be used to demons trate that the control device for the em ission point was operating in such a fashion to warrant assigning full or partial credits and debits. (4) The Administrator may assign fu ll 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 includ ed in an emissions average, the owner or operator shall perform testing, monitoring, recordkeeping, and reporting equivalent to thatrequired 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 109

loading racks, and marine tank vess els are identified in paragraphs (a)(1) through (a )(7) of this section. (1) The source shall im plement the following te sting, monitoring, recordkeeping, and reporting procedures for each miscellaneous process vent equipped with a fl are, incinerator, boiler, or process heater: (i) Conduct initial performance te sts to determine the percentage of reduction as specified in §63.645 of this subpart and §63.116 of subpart G; and (ii) Monitor the operatin g parameters specified in §63.644, as ap propriate for the specific control device. (2) The source shall implemen t the following procedures for each miscellaneous process vent, equipped with a carbon adsorber, ab sorber, or condenser but not e quipped with a control device: (i) Determine the flow rate a nd organic HAP concentration us ing the methods 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 opera ting parameters specified in §63.114 of subpart G, as appropriate for the specific recovery device. (3) The source shall implement the following procedures for each storage vesse l controlled with an internal floating roof, extern al roof, or a closed vent syst em 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 subp art 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 s ubpart R of this pa rt except §63.425(d) or §63.427(c). (5) For each marine tank vessel that is controlled, performthe compliance, monitoring, and performance testing, 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 wa stewater 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 109

(ii) Conduct inspections a nd 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 controll ed using a pollution prevention measure or a device or techni que for which no monitoring parame ters 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 info rmation specified in §63.655(h)(4) in the Implementation Plan. (b) Records of all information required to calculate emission de bits and credits and records required by §63.655 shall be re tained for 5 years. (c) Notifications of Compliance Status report, Periodic Reports, and ot her 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 fo r any emission points shall s ubmit an Implementation Plan. (1) The Implementation Plan shall be submitted to the Administrator a nd approved prior to implementing emissions averaging. This information may be subm itted in an operating permit application, in an amendment to an operating permit application, in a separate s ubmittal, 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 informati on specified in paragr aph (d)(2) of this section at different times, and/or in different submittals, later submittals may refer to earlier submittals instead of dupl icating the previously submitted information. (2) The Implementation Plan shall include the in formation specified in paragraphs (d)(2)(i) through (d)(2)(ix) of this section for all points in cluded in the average. (i) The identification of all em ission points in the planned e missions 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 eachemission point and the sum for the emission points involved in the average calcu lated according to §63.652. The annual projected credits must be greater th an 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 inthe average and date of application or expected date of application. (iv) The specific identification of each emission point aff ected by a pollution prevention measure. To be considered a pollution prevention me asure, 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 average, the owner or operator must id entify each of these emission points.Page 69 of 109

(v) A statement that the comp liance demonstration, monitoring, inspection, recordkeeping, and reporting provisions in para graphs (a), (b), and (c) of this section that are ap plicable to each emission point in the emissions average will be implemented beginning on the date of compliance. (vi) Documentation of the inform ation listed in paragraphs (d)(2)( vi)(A) through (d)(2)(vi)(D) of this section for each emission poi nt included in the average. (A) The values of the parameters used to deter mine 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 de bit and credit calculations in §63.652 (g) and (h). These parameter values or, as appropria te, limited ranges for the parameter values, shall be specified in th e source’s Implementati on Plan as enforceable operating conditions. Changes to th ese parameters must be reporte d in the next Periodic Report. (C) The estimated percentage of reduction if a control technol ogy achieving a lower percentage of reduction than the ef ficiency of the reference control te chnology, as defined in §63.641, is or will be applied to the emission point. (D) The anticipated nominal efficiency if a cont rol technology achieving a greater percentage emission reduction than the efficien cy of the reference control techno logy is or will be applied to the emission point. The proce dures in §63.652(i) shall be foll owed to apply for a nominal efficiency. (vii) The informa tion specified in §63.655(h)(4) for: (A) Each miscellaneous process vent controlled by a pollution preventi on 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 contro lled by a pollution prevention measur e or a control technique other than an internal or external floating roof or a cl osed vent system with a control device. (viii) Documentation of the information listed in para graphs (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 wastew ater stream is a Group 1 or Group 2 wastewater stream. (B) The estimated values of all pa rameters needed for input to the wastewater emission credit and debit calculations in §63.652(h)(6). (C) The estimated percentage of redu ction if the wastewater stream is or will be controlled using a treatment process or series of treatment proces ses that achieves an em ission reduction less than or equal to the emission reduction sp ecified in table 7 of this subpart.Page 70 of 109

(D) The estimated percentage of re duction if a control technology ac hieving less than or equal to 95 percent emission reduction is or will be applie d to the vapor stream(s ) vented an d collected from the treatment processes. (E) The estimated percentage of reduction if a po llution prevention measure is or will be applied. (F) The anticipated nominal efficiency if the owner or operator plans to apply for a nominal efficiency under §63.652(i). A nominal ef ficiency 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 achievi ng greater than 95 percent emission reduction is or will be applied to the vapor stream (s) vented and coll ected 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 speci fied 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) demons trating the hazard or risk equivalency of the proposed emissions average. (3) The Administrator shall determine within 120 calendar days whether the Implementation Plan submitted presents sufficient informati on. The Administrator shal l either approve the Implementation Plan, request changes, or reques t that the owner or op erator submit additional information. Once the Administrator receives su fficient information, the Administrator shall approve, disapprove, or re quest changes to the plan within 120 calendar days. § 63.654 Heat exchange systems. (a) Except as specified in paragr aph (b) of this section, the owner or operator of a heat exchange system that meets the criteria in§63.640(c)(8) must comply with th e requirements of paragraphs (c) through (g) of this section. (b) A heat exchange system is exempt from the requ irements 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) A a ll heat exchangers that are in organic HAP service within the heat exchange system that either: ( 1 i ) Operate with the minimum pressure on the coo ling water side at leas t 35 kilopascals greater than the maximum pressure on the process side; or ( 2 ii ) Employ an intervening cooling fluid , containing less than 5 pe rcent by weight of total organic HAP , as determined according to the provisi ons of §63.180(d) of subpart H of thisPage 71 of 109

part and listed in T t able 1 of to this subpart, between the proces s and the cooling water. This intervening fluid must serve to isolate the cooling water from th e process fluid a nd must not be sent through a cooling to wer or discharged. For purposes of this section, di scharge does not include emptying for ma intenance purposes. (2) The heat exchange system cools process fluids that contain less than 5 percent by weight of total HAP listed in Table 1 to this subpart (i.e ., the heat exchange syst em does not contain any heat exchangers that are in organic HAP service as defined in this subpart). (c) The owner or oper ator must perform monthly monitoring to identify le aks of total strippable volatile organic compound s (VOC) from each heat exchange sy stem subject to the requirements of this subpart according to the pr ocedures in paragraphs (c)(1) through and ( 6 2 ) of this section. (1) Monitoring locations for closed-loop recirculation heat exchange systems . For each closed loop recirculating heat exchange system, C c ollect and analyze a sample from the location(s) described in either paragraph (c)(1)(i ) or (c)(1)(ii) of this section. (i) e E ach cooling tower return line or any representative riser within the cooling tower prior to exposure to air for eac h heat exchange system in organic HAP service or

. (ii) Selected from each heat exchanger exit line (s) so that for each heat exchanger or group of heat exchangers in organic HAP service within a thatheat exchange system is covered by the selected monitoring location(s). (2) Monitoring locations for once-t hrough heat exchange systems . For each once-through heat exchange system, collectand analyze a sample from the location(s) described in paragraph (c)(2)(i) of this se ction. The owner or operator may also elect to collect and analyze an additional sample from the location (s) described in paragraph (c)(2)(ii) of this section. (i) Selected heat exch anger exit line(s) so that each heat exchanger or group of heat exchangers within a heat exchange system is c overed by the selected mo nitoring location(s). The selected monitoring location may be at a point where discharges from multiple heat exchange systems are combined provided that the combined cooling water flow rate at the monitoring location does no t exceed 40,000 gallons per minute. (ii) The inlet water feed line for a once-throug h heat exchange system prior to any heat exchanger. If multiple heat exchange systems use the same water feed ( i.e. , inlet water from the same primary water source), the owner or operator may monitor at one representative location and use the monitoring results for that sampling lo cation for all heat exchange systems that use that same water feed. (3) Monitoring method

. to d D etermine the total strippable hydrocarbon VOC concentration ( in parts per million by volume (ppmv) as methane) at each monitoring location from the air stripping testing system using the “Air Stripping Method (Modifi ed El Paso Method) for Determination of Volatile Organic Compound Emi ssions from Water Sour ces” Revision NumberPage 72 of 109

One, dated January 2003, Sampling Procedur es Manual, Appendix P: Cooling Tower Monitoring, prepared by Texas Commission on Environmental Qu ality, January 31, 2003 (incorporated by reference—see §63.14) using a flame ionization detector (FID) analyzer for on-site determination as des cribed in Section 6.1 of th e Modified El Paso Method

. (4) Monitoring frequency and leak ac tion level for existing sources . For a heat exchange system at an existing source, the owner or operator must comply with the monitoring frequency and leak action level as defined in paragraph (c)(4)(i) of this section or comply with the monitoring frequency and leak action level as defined in paragraph (c)(4)(ii) of this section. The owner or operator of an af fected heat exchange system may choose to comply with paragraph (c)(4)(i) of this section for some he at exchange systems at the petroleum refinery and comply with paragrap h (c)(4)(ii) of this section for other heat exchange systems. However, for each affected heat exchange system, the owner or operator of an 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 al ternative that applies to a heat exchange system, the owner or operat or must notify the Administrator 30 days in advance of such a change. All “leaks” identified prior to changing mo nitoring alternatives must be repaired. The monitoring frequencies sp ecified in paragraphs (c)(4)(i) and (ii) of this section also apply to the inlet water feed line for a once-through heat exchange system, if monitoring of the inlet wate r feed is elected as provided in paragraph (c)(2)(ii) of this section. The owner or operator of a once

- through heat exchange system may elect to also monitor monthly (in addition to mon itoring each heat exchanger exit line) the fresh water feed line prior to any heat exchanger to determ ine the total strippable VOC conc entration (as methane) prior to the heat exchange system using the Modified El Paso Method. ( i 2 ) For a heat exchange system at an existing source, Monitor monthly using a leak action level defined as is a total strippable hydrocarbon VOC concentration (as methan e) in the stripping gas of 6.2 ppmv or greater

. (ii) Monitor quarterly using a le ak action level defined as a total strippable hydrocarbon concentration (as methane) in the stripping gas of 3.1 ppmv unless repair is delayed as provided in paragraph (f) of this section. If a repair is delaye d as provided in paragraph (f) of this section, monitor monthly. (5) Monitoring frequency and leak action level for new sources

. For a heat exchange system at a new source, the owner or operator must monitor monthly using a leak action level defined as is a total strippable hydrocarbon VOC concentration (as methane) in the stripping gas of 3.1 ppmv or greater

. (6) Leak definition . A leak is defined as described in para graph (c)(6)(i) or (c )(6)(ii) of this section, as applicable. (i) For once-through heat exchan ge systems for which the inlet water feed is monitored as described in paragraph (c)(2)(ii) of this section, a leak is detected if the difference in the measurement value of the sample taken from a location specified in paragraph (c)(2)(i) of this section and the measu rement value of the correspondi ng sample taken from thePage 73 of 109

location specified in paragraph (c)(2)(ii) of th is section equals or exceeds the leak action level. (ii) For all other heat exchange systems, a leak is detected if a measurement value of the sample taken from a location speci fied in either paragraph (c)(1)(i ), (c)(1)(ii), or (c)(2)(i) of this section equals or exceeds the leak action level. (d) If a leak is detected, the owner or operator must repair the leak to reduce the measured concentration to below the applicable action le vel 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. Repair includes re-monitoring at the monitoring location where the leak was identified according to the method specified in paragrap h (c)(3) of this section to verify that the measured concentration is below the applicable action level. 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 in to the process fluid; (4) Replacing the heat exchange r 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) (i) of this section, the owner or oper ator may conduct additional monitoring to identify leaks of total stripp able VOC emissions using Modi fied 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 as provided under paragraph (c)(1)(ii) of this section

. If no leaks are detected when monitoring ac cording to the requirements of paragraph (c)(1)(ii) of this section the additional monitoring shows that the total strippable VOC concentration in the stripped air at the heat exchanger exit line for each heat exchan ger in organic HAP service is less than 6.2 ppmv for existing so urces or less than 3.1 ppmv for new sources , the heat exchange system is considered to meet the repair requirements through re-monitoring of the heat exchange system as provided excluded from r epair requirements in paragraph (d) of this section. (f) The owner or operator may de lay the repair of a leaking h eat exchanger when one of the conditions in paragraphs (f)(1) or and (f) (2) of this section is metand the leak is less than the delay of repair ac tion level specified in paragraph (f)(3) of this section . The owner or operator must determine if a delay of repair is necessary as soon as practicable, but no later than 45 days after first id entifying the leak.Page 74 of 109

(1) If the repair is technically infeasible without a shutdown and the total strippable hydrocarbon VOC concentration (as methane) is initially and remains less than the delay of repair action level 62 ppmv for all monthly monitoring period s during the delay of repair, the owner or operator may delay repair until the ne xt scheduled shutdown of the heat exchange system. If, during subsequentmonthly monitoring, the delay of repair action level is exceeded total strippable VOC concentration (as methane) is 62 ppmv or greater , the owner or operator must repair the leak w ithin 30 days of the monitoring ev ent in which the leak was equal to or exceeded the delay of repair action level 62 ppmv total strippable VOC (as methane), except as provided in paragr aph (f)(3) of this section

. (2) If the necessary equipment, parts, or pers onnel are not available and the total strippable hydrocarbon VOC concentration (as methane) is initially and remains less than the delay of repair action level 62 ppmv for all monthly monitoring period s 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 th e necessary equipment, parts, or personnel were not available. If, during subsequent monthly monitoring, the delay of repair acti on level is exceeded total strippable VOC concentration (a s methane) is 62 ppmv or greater , the owner or operator must repair the leak within 30 days of the monitoring event in which th e leak was equal to or exceeded the delay of repair action level 62 ppmv total s trippable VOC (as methane)

. (3) The delay of repair action level is a total strippable hydrocar bon concentration (as methane) in the stripping gas of 62 ppmv. The de lay of repair action level is assessed as described in paragraph (f)(3)(i) or (f)(3)( ii) of this section, as applicable. (i) For once-through heat exchan ge systems for which the inlet water feed is monitored as described in paragraph (c)(2)(ii) of this section, the delay of repair action level is exceeded if the difference in the measurement value of the sample taken from a location specified in paragraph (c)(2)(i) of this se ction and the measurement value of the corresponding sample taken from the location specified in paragraph (c)(2)(ii) of this section equals or exceeds the delay of repair action level. (ii) For all other heat exchange systems, the de lay of repair action le vel is exceeded if a measurement value of the sample taken from a location specified in either paragraphs (c)(1)(i), (c)(1)(ii), or (c)(2)(i) of this sectio n equals or exceeds the delay of repair action level. (g) To delay the repair under paragraph (f) of this section, the owner or operator must record the information in para graphs (g)(1) through (g) (4) of this section. (1) The reason(s) for delaying repair. (2) A schedule for completing th e repair as soon as practical. (3) The date and concentration of the leak as fi rst identified and the re sults of all subsequent monthly monitoring events dur ing the delay of repair.Page 75 of 109

(4) An estimate of the potential strippable hydrocarbon emissions from the leaking heat exchange system or heat exchanger for each required delay of re pair monitoring interval following the procedures in paragraphs (g)(4)(i) through and (g)(4) (i v i ) of this section. (i) Determine the leak total strippable VOC concentration as specified in paragraph (c) of this section and convert the stripping gas leak concentration (in ppmv as methane) to an equivalent liqui d concentration in the cooling water , in parts per million by weight (ppmw), using equation 7–1 from “Air Stri pping Method (Modified El Paso Method) for Determination of Volatile Organic Compound Emis sions from Water Sources” Re vision Number One, dated January 2003, Sampling Procedures Manual, Appendix P: Cooli ng Tower Monitoring, prepared by Texas Commission on Environmen tal Quality, January 31, 2003 (i ncorporated by reference— see §63.14) , and the molecular weight of 16 gr ams per mole (g/mol) for methane based on the total strippable concentration in th e stripped air, ppmv, from monitoring

. (ii) Determine the mass flow rate of the cooling water at the mo nitoring location where the leak was detected. If the monitoring location is an individual cooling tower riser, determine the total cooling water mass flow rate to the cooling tower. Cooling water mass flow rates may be determined using direct measurement, pump curves, heat balance calculations, or other engineering methods. Volumetric flow measurements may be used and converted to mass flow rates using the densit y of water at the specific moni toring location temperature or using the default density of water at 25 deg rees Celsius, which is 997 kilograms per cubic meter or 8.32 pounds per gallon. Calculate the VOC emissions fo r the leaking heat exchange system or heat exchanger by multiply ing the VOC concentration in the cooling water, ppmw, by the flow rate of the cooling wa ter from the leaking tower or h eat exchanger and by the expected duration of the delay. (iii) For delay of repair monitoring interval s prior to repair of the leak, calculate the potential strippable hydrocarbon emissions for the leaking heatexchange system or heat exchanger for the monitoring interval by mult iplying the leak concen tration in the cooling water, ppmw, determined in (g)(4 )(i) of this section, by the mass flow rate of the cooling water determined in (g)(4)(ii) of this section and by the dura tion of the delay of repair monitoring interval. The duration of the delay of repair monitoring interval is the time period starting at midnight on the day of th e previous monitoring event or at midnight on the day the repair would have had to be completed if the re pair had not been delayed, whichever is later, and ending at midnight of the day the of the current monitoring event. (iv) For delay of repair moni toring intervals ending with a repaired leak, calculate the potential strippable hydrocarbon emissions for the leaking heatexchange system or heat exchanger for the final delay of repair monito ring interval by multiplying the duration of the final delay of repair monitoring interval by the leak concentration and cooling water flow rates determined for the la st monitoring event prior to th e re-monitoring event used to verify the leak was repaired. The duration of th e final delay of repair monitoring interval is the time period starting at midnight of the da y of the last monitoring event prior to remonitoring to verify the leak was repaired and ending at the time of the re-monitoring event that verified that the leak was repaired.Page 76 of 109

§ 63.655 Reporting and recordkeeping requirements. (a) Each owner or operator subj ect to the wastewater provisions in §63.647 shall comply with the recordkeeping and reporting pr ovisions in §§61.356 and 61.357 of 40 CFR part 61, subpart FF unless they are complying with the wastewater pr ovisions specified in paragraph (o)(2)(ii) of §63.640. There are no additional reporting and record keeping requirements for wastewater under this subpart unless a wastewater stream is included inan emissions average. Recordkeeping and reporting for emissions averages are specified in §63.653 and in pa ragraphs (f)(5) and (g)(8) of this section. (b) Each owner or operator subject to the gaso line loading rack pr ovisions in §63.650 shall comply with the recordkeeping and reporting provisions in §6 3.428 (b) and (c), (g)(1), (h)(1) through (h)(3), and (k) of subpar t R. These requirements are su mmarized in table 4 of this subpart. There are no additional reporting and r ecordkeeping requirements for gasoline loading racks under this subpart unle ss a loading rack is included in an emissions average. Recordkeeping and reporting for em issions averages are specifiedin §63.653 and in paragraphs (f)(5) and (g)(8) of this section. (c) Each owner or operator subj ect to the marine tank vessel loading operation standards in §63.651 shall comply with the recordkeeping and reporting provisions in §63.567(a) and §63.567(c) through (k) of subpart Y. These requirements are summa rized in table 5 of this subpart. There are no additional reporting and reco rdkeeping requirements for marine tank vessel loading operations under this subpart unless marine tank vessel loading operati ons are included in an emissions average. Recordkeeping and reporting for emissions averages are specified in §63.653 and in paragraphs (f)(5) an d (g)(8) of this section. (d) Each owner or operator su bject to the equipment leaks st andards in §63.648 shall comply with the recordkeeping and re porting provisions in paragraphs (d)(1) through (d )(6) of this section. (1) Sections 60.486 and 60.487 of su bpart 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 th is part except for §§63.182(b), (c)(2), and (c)(4). (i) The signature of the owner or operator (or designate) whos e decision it was th at a repair could not be effected without a process shutdown is not required to be recorded. Instead, the name of the person whose decision it was that a repair co uld not be effected w ithout a process shutdown shall be recorded and retained for 2 years. (ii) [Reserved] (2) The Notification of Compliance Status re port required by §63.182(c) of subpart H and the initial semiannual report re quired by §60.487(b) of 40 CFR pa rt 60, subpart VV shall be submitted within 150 days of the compliance da te specified in §63.640(h); the requirements of subpart H of this part are summari zed in table 3 of this subpart.Page 77 of 109

(3) An owner or operator who determines that a compressor qu alifies 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 k eep a list of identification numbers for valves that are designated as leakless per §63.648(c)(10). (5) An owner or operator must id entify, either by list or locatio n (area or refining process unit), equipment in organic HAP service less than 300 hours per year within refining process units subject to this subpart. (6) An owner or operator must keep a list of r eciprocating pumps and comp ressors determined to be exempt from seal requirem ents as per §§63.648 (f) and (i). (e) Each owner or operator of a source subject to this subpart sh all submit the reports listed in paragraphs (e)(1) through (e)(3) of this section except as provid ed in paragraph (h)(5) of this section, and shall keep records as descri bed in paragraph (i) of this section. (1) A Notification of Compliance Status report as described in paragraph (f) of this section; (2) Periodic Reports as described in paragraph (g) of th is section; and (3) Other reports as described in paragraph (h) of this section. (f) Each owner or operator of a source subject to this subp art shall submit a Notification of Compliance Status report within 150 days afte r 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 vess els subject to the complia nce 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 section. This information may be submitted in an operating permit application, in an amendment to an operat ing permit application, ina separate submittal, or in any combination of the thre e. If the required information has been submitted before the date 150 days after the compliance date specified in §63.640(h), a separa te Notification of Compliance Status report is not required within 15 0 days after the complian ce dates specified in §63.640(h). If an owner or operator submits the information speci fied in paragraphs (f)(1) through (f)(5) of this s ection at different times, and/or in different submittals, later submittals may refer to earlier submittals in stead of duplicating and resubm itting the previously submitted information. Each owner or op erator of a gasoline loading rack classified under Standard Industrial Classification Code 2911 located withina contiguous area and under common control with a petroleum refinery subject to the standard s of this subpart shall submit the Notification of Compliance Status report required by subpart R of this part within150 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.Page 78 of 109

(i) For storage vessels, this report shall in clude the information specified in paragraphs (f)(1)(i)(A) thr ough (f)(1)(i)(D) of this section. (A) Identification of each storage vessel subject to this subpar t, and for each Group 1 storage vessel subject to this subpart, the inform ation 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 submi tted for a storage vessel subject 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 floati ng roof, external floa ting 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 antic ipated compliance date. ( 3 ) For storage vessels subject to the complianc e schedule specified in §63.640(h)(4) that are complying with §63.646 and the Gr oup 1 storage vessels descri bed in §63.640(l), the actual compliance date. (B) If a closed vent system and a control device other than a fl are 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 main tained, an explanation of the crit eria used for selection of that parameter (or parameters), and the frequency with which m onitoring will be performed; and either ( 2 ) The design evaluation documenta tion specified in §63.12 0(d)(1)(i) of subpartG, if the owner or operator elects to prep are a design evaluation; or ( 3 ) If the owner or operator elects to submit the results of a perform ance test, identification of the storage vessel and control device for which the performance test will be submitted, and identification of the emi ssion point(s) that share the control device with the storage vessel and for which the performance test will be conducted. (C) If a closed vent system and control device ot her than a flare is use d, the owner or operator shall submit: ( 1 ) The operating range for each monitoring parameter. The specified operating range shall represent the conditions for whic h the control device is being pr operly operated and maintained. ( 2 ) If a performance test is conducted instead of a design evaluation, resu lts of the performance test demonstrating that the contro l device achieves grea ter than or equal to the required control efficiency. A performance test con ducted prior to the compliance date of this subpart can be usedPage 79 of 109

to comply with this requireme nt, provided that the test wa s conducted using EPA methods and that the test conditions 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 content determinations, fl ow rate measurements, and exit velocity determinations made during the comp liance determination required by §63.120(e) of subpart G of this part; and ( 3 ) All periods during the compliance determin ation when the pilo t flame is absent. (ii) For miscellaneous process ve nts, identification of each miscella neous process vent subject to this subpart, whether the process vent is Gr oup 1 or Group 2, and the me thod 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 cont rol device meeting the re quirements 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, perfor mance test results including the informatio n in paragraphs (f)(1)(iii)(A) and (B) of this sect ion. Results of a performance test conducted prior to the compliance date of this subpart can be used provided that the test was conducted using th e methods specified in §63.645 and that the test conditions are representative of curre nt operating conditions. (A) The percentage of reduction of organic HAP’s or TOC, or the outlet concentrat ion of organic HAP’s or TOC (parts per mill ion by volume on a dry basis corr ected 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 permittin g authority, 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; (A) All visible emission readings, heat content determinations, fl ow rate measurements, and exit velocity determinations made during the comp liance determination required by §63.645 of this subpart and §63.116(a) of subp art G of this part, and (B) A statement of whether a flame was present at the pilot light over the full period of the compliance determination. (v) For equipment leaks comply ing with §63.648(c) (i.e., complyi ng with the requirements of subpart H of this part), the Notification of Compliance Report Status report information requiredPage 80 of 109

by §63.182(c) of subpart H and whether the percenta ge of leaking valves will be reported on a process unit basis or a sourcewide basis. (vi) For each heat exchange syst em, identification of th e heat exchange syst ems that are subject to the requirements of this subpart. For heat exchange systems at existing sources, the owner or operator shall indicate whether monito ring will be conduc ted as specified in §63.654(c)(4)(i) or §63.654(c)(4)(ii). (2) If initial performance tests are requir ed by §§63.643 through 63.653 of this subpart, the Notification of Compliance Status report shall include one comple te test report for each test method used for a particular source. (i) For additional tests performed using the same method, the results specifi ed in paragraph (f)(1) of this section shall be su bmitted, but a complete test report is not required. (ii) A complete test report sh all include a sampling site descri ption, description of sampling and analysis procedures and any modi fications to standard procedures , quality assurance procedures, record of operating conditions du ring the test, record of prepar ation of standards, record of calibrations, raw data sheets for field sampling, ra w 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 test s are required for some kinds of em ission points and controls. Periodic testing of the same emissi on point is not required. (3) For each monitored paramete r 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 Compli ance 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 speci fic range for each parameter for each emission point, including any data and calculations used to develop the range and a descrip tion of why the range ensures compliance with the emission standard. (A) If a performance test is requir ed by this subpart for a control device, the range shall be based on the parameter values measured during the performance test supplemented by engineering assessments and manufacturer’s recommendations. Pe rformance 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 c ontrol device, the range may be based solely on engineering assessment s and manufacturers’ recommendations.Page 81 of 109

(iii) A definition of the source’s operating day for purposes of de termining daily average values of monitored parameters. The definition shall speci fy the times at which an operating day begins and ends. (4) Results of any continuous m onitoring system performance eval uations shall be included in the Notification of Comp liance Status report. (5) For emission points included in an emissions average, the Notification of Compliance Status report shall include the va lues of the parameters needed for input to the emissi on credit and debit equations in §63.652(g) and (h), calculated or measured according to the procedures in §63.652(g) and (h), and the resulting credits and debits fo r the first quarter of the year. The first quarter begins on the compli ance date specified in §63.640. (6) Notification of Compliance St atus 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-m onth period during which the change or addition was made that resulted in the Group 1 emission poi nt or the existing Group 1 stor age vessel was brought into compliance, and may be combined with the period ic report. Six-month peri ods shall be the same 6-month periods specified in para graph (g) of this section. The No tification of Compliance Status report shall include the in formation specified in paragraphs (f)(1) through (f)(5) of this section. This information may be submitte d in an operating permit appli cation, in an amendment to an operating permit application, in a se parate submittal, as part of the periodic report, or in any combination of these four. If the required information has been s ubmitted 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 Compliance Status report is not re quired 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 differ ent submittals, later submittals may refer to earlier submittal s instead of duplicati ng and resubmitting the previously submitt ed information. (g) The owner or operator of a source subject to this subp art shall submit Periodic Reports no later than 60 days after the e nd of each 6-month period when any of the compliance exceptions specified in paragraphs (g)(1) throug h (6) of this section or paragra ph (g)(9) of this section occur. The first 6-month period shall begin on the date the Notification of Compli ance Status report is required to be submitted. A Peri odic Report is not re quired if none of th e compliance exceptions identified in paragraph (g)(1) through (6) of this section or paragraph (g)(9) of this section occurred during the 6-month peri od unless emissions averaging is utilized. Quarterly reports must be submitted for emission points included in emission aver ages, as provided in paragraph (g)(8) of this section. An owner or operator may submit reports re quired by other regulations in place of or as part of the Pe riodic Report required by this para graph if the reports contain the information required by paragraphs (g )(1) through (9) of this section. (1) For storage vessels, Periodic Reports sha ll include the information specified for Periodic Reports in paragraph (g)(2) through (g)(5) of th is section except that information related to gaskets, slotted membranes, and slee ve seals is not required for stor age vessels that are part of an existing source.Page 82 of 109

(2) An owner or operator who elects to co mply with §63.646 by using a fixed roof and an internal floating roof or by using an external floa ting roof converted to an internal floating roof shall submit the results of each inspection condu cted 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 re quired under §63.120(a)(2)(i ) or (a)(3)(ii) of subpart G of this part, the sp ecifications and requirements lis ted 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 floa ting roof is not resting on the surface of the liquid inside the st orage vessel and is not resting on the leg supports; or there is liquid on the floating roof; or the seal is detached from the intern al 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 para graph (g)(2)(i)(C) of this s ection, each Periodic Report shall include the date of the inspection, identification of each stor age vessel in which a failure was detected, and a description of the failure. The Periodic Re port shall also describe the nature of and date the repair was made or the date the storage 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 subpart G of this part; and de scribe the date the storage vessel was emptied and the nature of and date the repair was made. (ii) For vessels for which inspections are require d under §63.120(a)(2)(ii), (a )(3)(i), or (a)(3)(iii) of subpart G of this part (i.e., internal inspections), the specifica tions 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 ti me in which the internal floating roof has defects; or the primary seal has holes, tears, or other openings in the seal or the seal fabric; or the secondary seal (if one has been installed) has holes, tears, or other op enings in the seal or th e seal fabric; or, for a storage vessel that is part of a new source, the gaskets no longer close off the liquid surface from the atmosphere; or, for a storage vessel that is part of a new source, th e slotted membrane has more than a 10 percent open area. (B) Each Periodic Report shall include the date of the inspection, identif ication of each storage vessel in which a failure was detected, and a descri ption of the failure. Th e 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 ex ternal floating roof shall meet the periodic reporting requirements specified in paragr aphs (g)(3)(i) through (g)(3)(iii) of this section. (i) The owner or operator shall submit, as part of the Pe riodic Report, documentation of the results of each seal gap meas urement made in accordance with §63.120(b) of subpart G of thisPage 83 of 109

part in which the seal and s eal gap requirements of §63.120(b)(3), (b)(4), (b)(5), or (b)(6) of subpart G of this part are not me t. This documentation shall include the info rmation 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 th e seal gap measurement and th e calculations described in §63.120(b)(3) and (b)(4) of s ubpart G of this part. (C) A description of any seal condition 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 §63.120(b)(7)(ii) or (b)(8) of subpart G of this part, the owner or operat or shall, in the next Periodic Repor t, 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 date the vessel was emptied and the nature of and date the repair was made. (iii) The owner or operat or shall submit, as part of the Pe riodic Report, documentation of any failures that are identified during visual inspections require d by §63.120(b)(10) of subpart G of this part. This documentation shall meet the specifications and require ments 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 floa ting roof has defects; or the primary seal has holes or other op enings in the seal or the seal fabric; or the secondary seal has holes, tears, or other openings in th e seal or the seal fabr ic; or, for a storage vess el that is part of a new source, the gaskets no long er close off the liqui d surface 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, identif ication of each storage vessel in which a failure was detected, and a descri ption of the failure. Th e Periodic Report shall also describe the nature of and date the repair was made. (4) An owner or operator who elects to comply with §63.646 by using an ex ternal floating roof converted to an internal floati ng roof shall comply with the pe riodic 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 Pe riodic Report, the info rmation specified in paragraphs (g)(5)(i) through (g )(5)(iii) of this section. (i) The Periodic Report shall include the inform ation specified in para graphs (g)(5)(i)(A) and (g)(5)(i)(B) of this section for those planned routine maintenance operations that would requirePage 84 of 109

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 anti cipated to be performed for the control device during the next 6 months. This descrip tion shall include the type of maintenance necessary, planned frequency of maintenanc e, and lengths of maintenance periods. (B) A description of the planne d routine maintenance that was performed for th e control device during the previous 6 months. This description shall include the type of maintenance performed and the total number of hours durin g those 6 months that the cont rol device did not meet the requirements of §63.119 (e)(1) or (e)( 2) of subpart G of this part, as applicable, due to planned routine maintenance. (ii) If a control device other th an a flare is used, the Period ic Report shall describe each occurrence when the monitored parameters were outside of the parameter ranges documented in the Notification of Compli ance Status report. The de scription 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 Period ic Report shall describe each occu rrence 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 s ubpart A of this part. (6) For miscellaneous process vents for which continuous parameter monitors are required by this subpart, periods of excess em issions shall be identified in the Periodic Reports and shall be used to determine compliance with the emission standards. (i) Period of excess emission mean s any of the following conditions: (A) An operating day when the daily average value of a monitored paramete r, except presence of a flare pilot flame, is outside the range specified in the Notification of Co mpliance Status report. Monitoring data recorded during periods of m onitoring system breakdown, repairs, calibration checks and zero (low-level) and high-level adjus tments shall not be used in computing daily average values of monitored parameters. (B) An operating day when all pilo t flames of a flare are absent. (C) An operating day when monitoring data requiredto be recorded in paragraphs (i)(3) (i) and (ii) of this section are av ailable for less than 75 perc ent of the operating hours. (D) For data compression system s approved under paragraph (h)(5 )(iii) of this section, an operating day when the monitor oper ated for less than 75 percent of the operating hours or a day when less than 18 monitoring values were recorded.Page 85 of 109

(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 oper ating permit authority. (iii) Periods of startup and s hutdown that meet the definiti on of §63.641, and malfunction that meet the definition in §63.2 a nd periods of performance te sting and monitoring system calibration shall not be consider ed periods of excess emission s. Malfunctions may include process unit, control device, or monitoring system malfunctions. (7) If a performance test for determination of comp liance for a new emission point subject to this subpart or for an emission poi nt 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) Results of the performance test shall include the percentage of emissi ons reduction or outlet pollutant concentration reduction (whichever is needed to determine compliance) and the values of the monitored operating parameters. (ii) The complete test reportshall 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 calend ar days after the end of each quarter. The first report shall be submitted with the Notificati on of Compliance Status report no later than 150 days af ter the compliance da te specified in §63.640. (ii) The quarterly re ports shall include: (A) The informati on specified in this paragraph and in pa ragraphs (g)(2) thr ough (g)(7) of this section for all storage vessels a nd miscellaneous process vents includ ed 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 included in an emissions av erage, unless this inform ation has already been submitted in a separate report; (C) The information requ ired to be reported by §63.567(e)(4) and (j)(3) of subpart Y for each marine tank vessel loading operati on included in an emissions average, unless the information has already been submitte d 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 Implementa tion Plan for the source; (E) The credits and debits calcula ted each month during the quarter;Page 86 of 109

(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 qu arter or that have changed si nce the previous quarter; and (H) Any other information the sour ce is required to report under the Implem entation Plan for the source. (iii) Every fourth quarterly repo rt shall include the following: (A) A demonstration that a nnual credits are gr eater than or equal to annu al debits as required by §63.652(e)(3); and (B) A certification of compliance with all the emissions averagi ng provisions in §63.652 of this subpart. (9) For heat exchange systems, Periodic Re ports must include the following information: (i) The number of heat exchange systems at the plant site subject to the monitoring requirements in §63.654 in HAP service

. (ii) The number of h eat exchange systems at the plant site in HAP service found to be leaking. (iii) For each monitoring location where the total strippable hydrocarbon concentration was A summary of the monitoring data that indicate a leak, including the number of leaks determined to be equal to or greater than the applicable leak definitions specified in §63.654(c)( 6 2 ) , identification of the moni toring location (e.g., unique monitoring location or heat exchange system ID number), the measured total strippable hydrocarbon concentration, ; (iv) If applicable, the date the a leak was first identified, and, if applicable, the date the source of the leak was identified ; , (iv) For leaks that were repaired during the reporting period (inclu ding delayed repairs), identification of the monitoring location a ssociated with the repa ired leak, the total strippable hydrocarbon concentr ation measured during re-moni toring to verify repair, and the re-monitoring date (i.e., the effective date of repair ) ; and (v) For If applicable, a summary of each delayed repair, including identification of the monitoring location associated with the leak for which repair is delayed, the original date when the delay of repair began, and reason for the d elay and the date of repair is expected to be completed , ( if the leak is not repaired during the reporting period ) ; the total strippable hydrocarbon concentration and date of each monitoring ev ent conducted on the delayed repair during the reporting period, andPage 87 of 109

(vi) If applicable, an estimate of the potential strippable hydrocarbon VOC emissions for each delayed repair over the reporting periodassociated with the delayed repair

. (h) Other reports shall be submit ted as specified in subpart A of this part and as follows: (1) Reports of startup, shutdown, and malfunctio n required by §63.10(d)(5). Records and reports of startup, shutdown, and malfunctio n are not required if they pe rtain solely to Group 2 emission points, as defined in §63.641, that ar e not included in an emissions average. For purposes of this paragraph, startup and shutdown shall have th e 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 afford the Admini strator the opportunity to have an observer present, the owner or operator shall notify the Administrator of the refilling of each Group 1 st orage 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 vessel prio r to refilling. (B) Except as provided in paragr aph (h)(2)(i)(C) of this sectio n, if the internal inspection required by §§63.120(a)(2), 63.120(a)(3), or 63.120(b)(1 0) of subpart G of this part is not planned and the owner or opera tor could not have known about the inspection 30 calendar days in advance of refilling the vessel with organi c HAP’s, the owner or op erator shall notify the Administrator at least 7 calendar da ys prior to refilling of the st orage vessel. Notification may be made by telephone and immediately followed by wr itten 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 calendar days prior to the refilling. (C) The State or local permitting authority can waive the notificati on 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 subpart. 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 soon er than 7 days after submitting the notification required by paragraph (h)(2)(i)(B) of this section for all storage vess els, or for individual storage vessels on a case-by-case basis. (ii) In order to afford the Admi nistrator the opportunity to have an observer present, the owner or operator of a storage vessel equipp ed with an external floating r oof shall notify the Administrator of any seal gap measurements. The notification shall be made in wr iting at least 30 calendar days in advance of any gap measurem ents required by §63.120 (b)(1) or (b)(2) of subpart G of thisPage 88 of 109

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 request ap proval for a nominal control efficiency for use in calculating credits for an emissions average, the information specified in §63.652(h). (4) The owner or operator who requests approval to monito r 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. For new or reconstructed sources, the information shall be submitted with the app lication for approval of construction or reconstruction re quired by §63.5(d) of subpart A and for existing sour ces, and the information shall be submitted no later than 18 months 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 m onitored to determine whether excess emissions occur and an explanation of the criteri a used to select the parameter(s). (ii) A description of th e methods and procedures that will be used to demonstrate that the parameter can be used to determine excess emis sions and the schedule for this demonstration. The owner or operator must cert ify that they will establish a ra nge for the monitored parameter as part of the Notification of Compliance Status report required in paragr aphs (e) and (f) of this section. (iii) The frequency and content of monitori ng, recording, and reporti ng if: monitoring and recording are not continuous ; or if periods of exce ss emissions, as defined in paragraph (g)(6) of this section, will not be identifi ed in Periodic Reports required under paragraphs (e) and (g) of this section. The ration ale for the proposed monitoring, reco rding, 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 listed in paragraph (i) of this section. (i) Requests shall be submitt ed with the Application for Approval of Construction or Reconstruction for new sources a nd no later than 18 months prio r to the compliance date for existing sources. The information may be submitte d in an operating permitapplication, in an amendment to an operating permit application, or in a separate submittal. Re quests shall contain the information specified in paragr aphs (h)(5)(iii) through (h)(5)(iv) of this s ection, as applicable. (ii) The provisions in §63 .8(f)(5)(i) of subpart A of this partshall govern the re view and approval of requests. (iii) An owner or operator may request approval to use an auto mated data compression recording system that does not record m onitored operating parameter valu es at a set frequency (forPage 89 of 109

example, once every hour) but records all values that m eet set criteria for variation from previously recorded values. (A) The requested system shall be designed to: ( 1 ) Measure the oper ating parameter value at least once every hour. ( 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 func tioning properly, alert the operator, and record the incident. ( 5 ) Compute daily average values of the monitored operating para meter based on recorded data. (B) The request shall contain a description of the monitoring system and data compression recording system including the cr iteria 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 approv al to use other altern ative 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 inform ation specified in para graphs (h)(6)(i) through (h)(6)(iii) of this section, as applicable. For existing sources, this information sh all be submitted in the initial Notification of Comp liance Status report. For a new source, the information shall be submitted with the applicati on for approval of constructi on or reconstruction required by §63.5(d) of subpart A of this pa rt. The information may be su bmitted in an operating permit application, in an amendment to an operating permit application, or ina separate submittal. (i) The determination of applicabil ity of this subpart to petroleu m refining process units that are designed and operated as flexible operation units. (ii) The determination of applicab ility of this subpart to any stor age vessel for which use varies from year to year. (iii) The determination of applicability of this subpart to any distillation unit for which use varies from year to year. (7) The owner or operator of a heat exchange sy stem at an existing so urce must notify the Administrator at least 30 cale ndar days prior to changing from one of the monitoring options specified in §63.654(c)(4) to the other.Page 90 of 109

(i) Recordkeeping . (1) Each owner or operator subject to the storage vess el 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 s eals are not required for storage vessels within existing sources. (ii) All references to §63.122 in §63.123 of subpar t G of this part shall be replaced with §63.655(e), (iii) All references to §63.150 in §63.123 of subpart G of this part sha ll be replaced with §63.652. (iv) If a storage vessel is dete rmined to be Group 2 because the weight percent total organic HAP of the stored liquid is less thanor equal to 4 percent for exis ting sources or 2 percent for new sources, a record of any data, assumptions, and pr ocedures used to make this determination shall be retained. (2) Each owner or operator requi red to report the results of perfo rmance 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 paragra ph (f)(2)(ii) of this section fo r each emission point tested. (3) Each owner or operator required to con tinuously monitor operating parameters under §63.644 for miscellaneous process vents or unde r §§63.652 and 63.653 for emission points in an emissions average shall keep the r ecords 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 sy stem shall measure data valu es at least once every hour. (ii) The owner or operat or shall record either: (A) Each measured data value; or (B) Block average values for 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 cal culate the hourly (or shorter pe riod) block average instead of all measured values. (iii) Daily average values of eac h continuously monitored paramete r shall be calculated for each operating day and retained for 5 year s except as specified in paragra ph (i)(3)(iv) of this section. (A) The daily average shall be calculated 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 hour s of operation per day if operation is not continuous.Page 91 of 109

(B) The operating day shall be the period define d in the Notification of Compliance Status report. It may be from midnight to midnight or anothe r daily period. (iv) If all recorded values for a monitored parameter during an ope rating day are within the range established in the Notification of Compliance Status report, th e 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 da ys, the records required in paragraph (i)(3)(ii) of this section shall also be retained for 5 years. (v) Monitoring data recorded during periods of monitoring sy stem breakdowns, repairs, calibration checks, and zero (low-l evel) and high-level adjustments shall not be included in any average computed under this subpart. Records shall be kept of the times and durati ons of all such periods and any other periods duri ng process or control device op eration when monitors are not operating. (4) The owner or operat or of a heat exchange system subject to this subpart the monitoring requirements in §63.654 shall comply with the recordke eping requirements in paragraphs (i)(4)(i) through (v i ) of this sectionand retain these records for 5 years

. (i) Identification of all petroleum refinery process unit heat exchangers at the facility and the average annual HAP concentration of process flui d or intervening coolin g fluid estimated when developing the Notification of Compliance Status report. (ii) Identification of all heat exchange systems subject to the monito ring requirements in §63.654 and identification of all heat exchan ge systems that are exempt from the monitoring requirements according to the provisions in §63.654(b) that are in organic HAP service . For each heat exchange sy stem that is subject to the monitoring requirements in §63.654 this subpart , this must include identification of all heat exchangers within each heat exchange system, identification of the indi vidual heat exchangers in organic HAP service within each heat exchange system, and, for closed-loop recirculati on systems, the cooling tower included in each heatexchange system. (iii) Results of the followi ng monitoring data for each required monthlymonitoring event: (A) Date/time of event. (B) Barometric pressure. (C) El Paso air strippi ng apparatus water flow milliliter/minute (ml/min) and air flow, ml/min, and air temperature, °C elsius

. (D) FID reading (ppmv). (E) Length of sampling period Heat exchang e exit line flow or cooling tower return line flow at the El Paso monitoring location, gal/min

.Page 92 of 109

(F) Sample volume. (G) Calibration information identif ied in Section 5.4.2 of the “Air Stripping Method ( Modified El Paso Method ) for Determination of Volatile Or ganic 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 in§63.14 (n ). (iv) The date when a leak was identified , the date the source of th e leak was identified, and the date when the heat exch anger was repaired or taken out of service. (v i ) If a repair is delayed, the reason for the de lay, the schedule for completing the repair, the heat exchange exit line flow or cooling tower return line average flow rate at the monitoring location (in gallons/minute), and the estimate of potential strippable hydrocarbon emissions for each required monitoring interval during the delay of repair. (5) All other information required to be reported under paragraphs (a) thro ugh (h) of this section shall be retained for 5 years. § 63.656 Implementation and enforcement. (a) This subpart can be implemented and enforc ed 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 the U.S. EPA, has the authority to implement and enforce this subpart. Contact the applicable U.S. EPA Regional Office to find out if implementati on and enforcement of this subpart is delegated to a State, local, or Tribal agency. (b) In delegating implementation and enforcement authority of this subpart to a State, local, or Tribal agency under subpart E of this part, the authorities co ntained in paragraph (c) of this section are retained by the Admini strator of U.S. EPA and cannot be transferred to the State, local, or Tribal agency. (c) The authorities that cannot be delegated to State, local, or Trib al agencies are as specified in paragraphs (c)(1) through (4) of this section. (1) Approval of alternativ es to the requirements in §§63.640, 63.642(g) through (l), 63.643, 63.646 through 63.652, and 63.654. Where th ese standards reference a nother subpart, the cited provisions will be delegated according to the dele gation provisions of the referenced subpart. Where these standards reference another subpart and modify the requirements, the requirements shall be modified as described in this subpart. Delegation of the modified requirements will also occur according to the delegation provi sions 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.Page 93 of 109

(3) Approval of major altern atives to monitori ng under §63.8(f), as defined in §63.90, and as required in this subpart. (4) Approval of major alternatives to recordk eeping 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—Tables

Table 1—Hazardous Air Pollutants Chemical name CAS No. a Benzene 71432 Biphenyl 92524 Butadiene (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) (e thylene dibromide) 106934 Dichloroethane (1,2) 107062 Diethanolamine 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 Xylene (mixed isomers b ) 1330207 xylene (m-) 108383 xylene (o-) 95476 xylene (p-) 106423

a CAS number = Chemical Abstract Service registry number as signed to specific compounds, isomers, or mixt ures of compounds.Page 94 of 109

b Isomer means all structural arrangements for the same number of atom s of each element and does not mean salts, es ters, or derivatives.

Table 2—Leak Definitions for Pumps and Valves Standard aPhase Leak definition (parts per million) §63.163 (pumps) I 10,000 II 5,000 III 2,000 §63.168 (valves) I 10,000 II 1,000 III 1,000

a Subpart H of this part.Page 95 of 109

Table 3—Equipment Leak Recordkeeping and Reporting Requirements for Sources Complying With §63.648 of Subpart CC by Co mpliance With Subpart H of this Part a Reference (section of subpart H of

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 inspection 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 record. 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 compliance 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 fo r §§63.182 (d)(2)(vii), (d)(2)(viii), and (d)(3).

a This table does not include all the requirement s delineated unde r the referenced sections. See referenced sections for specific requirements.Page 96 of 109

Table 4—Gasoline Distribution Emission Point Recordkeeping and Reporting Requirements a Reference (section of subpart 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 requirement s delineated unde r the referenced sections. See referenced sections for specific requirements.Page 97 of 109

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 Compliance Status report required under 40 CFR part 63, subpart CC. 63.565(b) Performance test data requirements 63.567(a) General Provis ions (subpart A) applicability 63.567(c) Request for extension of compliance 63.567(d) Flare recordkeeping requirements 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 collection 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 recordkeeping procedures

a This table does not include all the requirement s delineated unde r the referenced sections. See referenced sections for specific requirements.Page 98 of 109

Table 6—General Provisions Applicability to Subpart CC a

Reference Applies to subpart CC Comment 63.1(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 this table. 63.1(d) No Reserved. 63.1(e) No No CAA section 112(j) st andard 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 in 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-refe rence to §63.9(b) is changed to §63.9(b)(4) and (5). Subpart CC override s §63.9 (b)(2). 63.5(b)(5) No Reserved. 63.5(b)(6) YesPage 99 of 109

Reference Applies to subpart CC Comment 63.5(c) No Reserved. 63.5(d)(1)(i) Yes Except that the appli cation shall be submitted as soon as practicable before startup, but no later than 90 days after the promulgation date of subpartCC 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 aff ected sources subject to subpart CC, emission estimates specified in §63.5(d)(1)(ii)(H) are not required. 63.5(d)(1)(iii) No Subpart CC §63.655(f) speci fies 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 complian ce 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 specifi es 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, shut down, or malfunction plan does not apply to Group 2 emission point s that are not part of an emissions averaging group. b 63.6(e)(2) No Reserved. 63.6(e)(3)(i) Yes Except th e startup, shutdown, or ma lfunction plan does not apply to Group 2 emission point s 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 report s specified in §63.6(e)(3 )(iv) do not need to be reported within 2 and 7 days of commencing and completing the action, respectivel y, but must be included in the next periodic report. 63.6 (f)(1) Yes Except for the heat exch ange system standards, which apply at all times.Page 100 of 109

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 em ission test not required in subpart CC. 63.6(h)(5) No Visible emission requirem ents and timing is specified in §63.645(i) of subpart CC. 63.6(h)(6) Yes 63.6(h)(7) No Subpart CC does no t require opacity standards. 63.6(h)(8) Yes 63.6(h)(9) No Subpart CC does no t 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 Notification 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 re quires notification of pe rformance test at least 30 days (rather than 60 days) prior to the performance test. 63.7(c) No Subpart CC does not requ ire 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 ca pacity 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 additiona l 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 subm ittal by the date the sitespecific test plan is due, the da te shall be 90 days prior to the Notification of Compliance Status report in §63.655(f). 63.7(h)(4)(i) YesPage 101 of 109

Reference Applies to subpart CC Comment 63.7(h)(4)(ii) No Site-specific test pl ans 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 Except that verification of operational stat us shall, at a minimum, include completion of the manufacturer’s written specifications or recommendatio ns for installation, operation, and calibration of the system or other written procedures that provide adequate assurance that the equipment would monitor accurately. 63.8(c)(4) Yes Except subp art 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 evalua tion 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 subm itting 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 s ubmitting request is specified in §63.655(h)(5)(i) of subpart CC. 63.8(f)(5) Yes 63.8(f)(6) No Subpart CC does not requ ire continuous em ission 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 notneed to send a copy of each notification submittedto the Region al 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 requi red in §63.9(b)(1)(iii).Page 102 of 109

Reference Applies to subpart CC Comment 63.9(b)(2) No A separate Initial Noti fication 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) No Subpart CC requires notifi cation 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 requir e advanced notifi cation of visible emissions test. 63.9(g) No 63.9(h) No Subpart CC §63.655(f) specifi es 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 103 of 109

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 requi red by §63.10(d)(5)(i) may be submitted at the same time as periodic reports specified 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 consis tent with the startup, shutdown, and malfunction plan and that cause the source to exceed any applicable emission limitation do not need to be reported within 2 and 7 days of co mmencing 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). Submittal s shall be sent by the specified dates, but a postmark is not required.

b The plan, and any records or reports of startup, shutdown, an d malfunction do not apply to Group 2 emission points that are not part of an em issions averaging group.Page 104 of 109

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 mF e Fr Benzene 71432 1.00 0.80 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-) 108383 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 Chemi cal Abstracts Service registrynumber assigned to specific compounds, isomers, or mixtures of compounds.

Table 8—Valve Monitoring Frequency 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 calcula ted as a rolling average of tw o consecutive monitoring periods.

b QIP=Quality improvement program. Specified in §63.175 of subpart H of this part.Page 105 of 109

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 calcula ted as a rolling average of tw o consecutive monitoring periods.

b QIP=Quality improvement program. Specified in §63.175 of subpart H of this part.Page 106 of 109

Table 10—Miscellaneous Process Vents—Monitoring, Recordkeeping and Reporting Requirements for Complying With 98 Weight -Percent Reduction of Total Organic HAP Emissions or a Limit of 20 Pa rts Per Million by Volume

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monitored 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 temperature 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 Temperature upstream and downstream of the catalyst bed (63.644(a)(1)(ii)) 1. Continuous records c

.

2. Record an d report the upstream and downstream temperatures and the temperature difference across the catalyst bed av eraged over the full period of the performance 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 operating permit— PR g

.Page 107 of 109

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monitored 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 established 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 whether 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 108 of 109

Control device Parameters to be monitored a Recordkeeping and reporting requirements for monitored 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 atmosphere 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 not 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 h eat 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 record ed parameter values fo r the operating day. If all recorded values during an operati ng day are within the range 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 durat ion of the period when monito ring 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 boilers and pr ocess heaters with a design heat capacity ≥ 44 megawatts or for boilers and process heaters wher e all vent streams are introduced into the flame zone. No recordkeeping or reporti ng associated with m onitoring is required for such boilers and process heaters.Page 109 of 109

i Process vents that are routed to refinery fuel gas systems are notregulated under this subpart. No monitoring, recordkeeping, or reporting is required for boilers and process heaters that combust refinery fuel gas.