Page **1** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only For the reasons set out in the preamble, title 40, chapter I of the Code of Federal Regulations is amended as follows: PART 60

— [AMENDED] 1. The authority citation for part 60 continues to read as follows: Authority: 42 U.S.C. 7401, et seq . **Subpart OOOO —**  **[ Amended]**  **Subpart OOOO —**  **Standards of Performance for Crude Oil and Natur al**  **Gas Production, Transmission and Distribution** 
**Sec.** 60.5360 What is the purpose of this subpart? 60.5365 Am I subject to this subpart? 60.5370 When must I comply with this subpart? 60.5375 What standards apply to gas well affected facilities? 60.5380 What standards apply to centrifugal compressor affected facilities? 60.5385 What standards apply to reciprocating compressor affected facilities? 60.5390 What standards apply to pneum atic controller affected facilities? 60.5395 What standards apply to storage vessel affected facilities? 60.5400 What equipment leak standards apply to affected facilities at an onshore natural gas processing plant? 60.5401 What are the exceptions to the e quipment leak standards for affected facilities at onshore natural gas processing plants? 60.5402 What are the alternative emission limitations for equipment leaks from onshore natural gas processing plants? 60.5405 What standards apply to sweetening units at onshore natural gas processing plants? 60.5406 What test methods and procedures must I use for my sweetening units affected facilities at onshore natural gas processing plants? 60.5407 What are the requirements for monitoring of emissions and operation s from my sweetening unit affected facilities at onshore natural gas processing plants?Page **2** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only 60.5408 What is an o ptional procedure for measuring hydrogen sulfide in acid gas

— Tutwiler Procedure? 60.5410 How do I demonstrate initial compliance with the standards for my gas well affected facility, my centrifugal compressor affected facility, my reciprocating compressor affected facility, my pneumatic controller affected facility, my storage vessel affected facility, and my equipment leaks and sweetening unit affect ed facilities at onshore natural gas processing plants? 60.5411 What additional requirements must I meet to determine initial compliance for my covers and closed vent systems routing emissions from storage vessels or centrifugal compressor wet seal fluid d egassing systems ? 60.5412 What additional requirements must I meet for determining initial compliance with control devices used to comply with the emission standards for my storage vessel or centrifugal compressor affected facility? 60.5413 What are the pe rformance testing procedures for control devices used to demonstrate compliance at my storage vessel or centrifugal compressor affected facility? 60.5415 How do I demonstrate continuous compliance with the standards for my gas well affected facility, my ce ntrifugal compressor affected facility, my stationary reciprocating compressor affected facility, my pneumatic controller affected facility, my storage vessel affected facility, and my affected facilities at onshore natural gas processing plants? 60.5416 W hat are the initial and continuous cover and closed vent system inspection and monitoring requirements for my storage vessel or centrifugal compressor affected facility? 60.5417 What are the continuous control device monitoring requirements for my storage vessel or centrifugal compressor affected facility? 60.5420 What are my notification, reporting, and recordkeeping requirements? 60.5421 What are my additional recordkeeping requirements for my affected facility subject to VOC requirements for onshore natu ral gas processing plants? 60.5422 What are my additional reporting requirements for my affected facility subject to VOC requirements for onshore natural gas processing plants?Page **3** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only 60.5423 What additional recordkeeping and reporting requirements apply to my sweetening unit affected facilities at onshore natural gas processing plants? 60.5425 What part s of the General Provisions apply to me? 60.5430 What definitions apply to this subpart? Table 1 to Subpart OOOO of part 60

– Required Minimum Initial SO 2 Emissi on Reduction Efficiency (Z i ) Table 2 to Subpart OOOO of part 60

– Required Minimum SO 2 Emission Reduction Efficiency (Z c ) Table 3 to Subpart OOOO of part 60

– Applicability of General Provisions to Subpart OOOO

**Subpart OOOO —**  **Standards of Performance for Cr ude Oil and Natur**  **al Gas Production, Transmission**  **and Distribution §60.5360 What is the purpose of this subpart?**  This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds (VOC) and sulfur dioxide (S O 2 ) emissions from affected facilities that commence construction, modification or reconstruction after August 23, 2011. **§60.5365 Am I subject to this subpart?** You are subject to the applicable provisions of this subpart i f you are the owner or operator of one or more of the onshore affected facilities listed in paragraphs (a) through (g) of this section for which you commence construction, modification or reconstruction after August 23, 2011. (a) Each gas well affected facility, which is a single
natur al gas well. (b) Each centrifugal compressor affected facility, which is a single centrifugal compressor using wet seals that is locatedPage **4** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only between the wellhead and the point of custody transfer to the natural gas transmission and storage segment. A centrif ugal compressor located at a well site , or an adjacent well site and servicing more than one well site, is not an affected facility under this subpart. (c) Each reciprocating compressor affected facility, which is a single reciprocating compressor locat ed between the wellhead and the point of custody transfer to the natural gas transmission and storage segment. A reciprocating compressor located at a well site , or an adjacent well site and servicing more than one well site, is not an affected facility un der this subpart. (d) (1) For the oil production segment (between the wellhead and the point of custody transfer to an oil pipeline), each pneumatic controller affected facility, which is a single continuous bleed natural gas

- driven pneumatic controller

o perating at a natural gas bleed rate greater than 6 scfh. ( 2 ) For the natural gas production segment (between the wellhead and the point of custody transfer to the natural gas transmission and storage segment and not including natural gas processing plan ts), each pneumatic controller affected facility, which is a single continuous bleed natural gas

- driven pneumatic controller operating at a natural gas bleed rate greater than 6 scfh

.Page **5** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (3) For natural gas processing plants, each pneumatic controller affect ed facility, which is a single continuous bleed natural gas

- driven pneumatic controller

. (e) Each storage vessel affected facility, which is a single storage vessel , located in the oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment and has the potential for VOC emissions equal to or greater than 6 tpy taking into account requirements under a legally and practically enforceable limit in an operating permit or by other mechanism

. A storage v essel affected facility that subsequently has its potential for VOC emissions decrease to less than 6 tpy shall remain an affected facility under this subpart. A s torage vessel that has
d etermined in accordance with § 60.5395 (c) to have a potential to emit of less than 6 tpy is not a storage vessel affected facility , provided that the owner or operator has maintained record of such determination

. (f) The group of all equipment, except compressors, within a process unit is an affected facility. ( 1 ) Addi tion or replacement of equipment for the purpose of process improvement that is accomplished without a capital expenditure shall not by itself be considered a modification under this subpart.Page **6** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( 2 ) Equipment associated with a compressor station, dehydr ation unit, sweetening unit, underground storage vessel , field gas gathering system, or liquefied natural gas unit is covered by §§60.5400, 60.5401, 60.5402, 60.5421 , and 60.5422 of this subpart if it is located at an onshore natural gas processing plant. Equipment not located at the onshore natural gas processing plant site is exempt from the provisions of
§§ 60.5400, 60.5401, 60.5402, 60.5421 , and 60.5422 of this subpart. ( 3 ) The equipment within a process unit of an a ffected facilit y located at onshore n atural gas processing plants and described in paragraph (f) of this section are exempt from this subpart if they are subject to and controlled according to subparts VVa, GGG or GGGa of this part. (g) Sweetening units located at onshore natural gas
process ing plants that process natural gas produced from either onshore or offshore wells. (1) Each sweetening unit that processes natural gas is an affected facility; and (2) Each sweetening unit that processes natural gas followed by a sulfur recovery unit is an affected facility. (3) Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H 2 S) in the acid gas (expressed as sulfur) are required to comply with recordkeepingPage **7** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only and reporting requirements specified in §60.54 23(c) but are not required to comply with §§60.5405 through 60.5407 and
§§ 60.5410(g) and 60.5415(g) of this subpart. (4) Sweetening facilities producing acid gas that is completely reinjected into oil

- or - gas - bearing geologic strata or that is otherwise no t released to the atmosphere are not subject to §§60.5405 through 60.5407, 60.5410(g), 60.5415(g), and 60.5423 of this subpart. (h) The following provisions apply to gas well facilities that are hydraulically refractured. (1) A gas well facility that con ducts a well completion operation following hydraulic refracturing is not an affected facility, provided that the requirements of § 60.5375 are met. For purposes of this provision, the dates specified in
§ 60.5375(a) do not apply, and such facilities, as of October 15, 2012, must meet the requirements of § 60.5375(a)(1) through (4)
. (2) A well completion operation following hydraulic refracturing at a gas well facility not conducted pursuant to
§ 60.5375 is a modification to the gas well affected facility. (3 ) Refracturing of a gas well facility does not affect the modification status of other equipment, process units, storage vessels, compressors, or pneumatic controllers located at the well site.Page **8** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (4) Sources initially constructed after August 23, 2011, are considered affected sources regardless of this provision. **§60.5370 When must I comply with this subpart?** (a) You must be in compliance with the standards of this subpart no later than October 15, 2012 or upon startup, whichever is later. (b) The provisi ons for exemption from compliance during periods of startup, shutdown and malfunctions provided for in 40 CFR 60.8(c) do not apply to this subpart. (c) You are exempt from the obligation to obtain a permit under 40 CFR part 70 or 40 CFR part 71, provided you are not otherwise required by law to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a). Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart. **§60.5375 What standards apply to gas well**  **affected faci lities?**  If you are the owner or operator of a gas well affected facility, you must comply with paragraphs (a) through ( f ) of this section. (a) Except as provided in paragraph (f) of this section, for each well completion operation with hydraulic fractur ing begun prior to January 1, 2015, you must comply with the requirements of paragraph s (a)(3) and (4) of this section unless a more stringent state or local emission control requirement isPage **9** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only applicable; optionally, you may comply with the requirements of
pa ragraphs (a)(1) through (4) of this section. For each new well completion operation with hydraulic fracturing begun on or after January 1, 2015, you must comply with the requirements in paragraphs (a)(1) through ( 4 ) of this section. (1) For the duration o f flowback , route the recovered liquids into one or more storage vessels or re - inject the recovered liquids into the well or another well, and route the recovered gas into a gas flow line or collection system , re inject the recovered gas into the well or a nother well, use the recovered gas as an on

- site fuel source, or use the recovered gas for another useful purpose that a purchased fuel or raw material would serve, with no direct release to the atmosphere

. If this is infeasible, follow the requirements in paragraph (a)(3) of this section. (2) All salable quality gas must be routed to the gas flow line as soon as practicable. In cases where flowback emissions cannot be directed to the flow line, you must follow the requirements in paragraph (a)(3) of this section. (3) You must capture and direct flowback emissions to a completion combustion device, except in conditions that may result in a fire hazard or explosion, or where high heat emissions from a completion combustion device may negatively impact tundr a, permafrost or waterways. Completion combustionPage **10** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only devices must be equipped with a reliable continuous ignition source over the duration of flowback. (4) You have a general duty to safely maximize resource recovery and minimize releases to the atmosphere d uring flowback and subsequent recovery. (b) You must maintain a log for each well completion operation at each gas well affected facility. The log must be completed on a daily basis for the duration of the well completion operation and must contain th e records specified in §60.5420(c)(1)(iii). (c) You must demonstrate initial compliance with the standards that apply to gas well affected facilities as required by §60.5410. (d) You must demonstrate continuous compliance with the standards that apply to gas well affected facilities as required by §60.5415. (e) You must perform the required notification, recordkeeping and reporting as required by §60.5420. (f) (1) For each gas well affected facility specified in paragraphs (f)(1)( i ) and ( ii ) of this section, you must comply with the requirements of paragraphs (f)(2) and (3) of this section.Page **11** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( i ) Each well completion operation with hydraulic fracturing at a gas well affected facility meeting the criteria for a wildcat or delineation well. ( ii ) E ach well completion operation with hydraulic fracturing at a gas well affected facility meeting the criteria for a non

- wildcat low pressure gas well or non

- delineation low pressure gas well. (2) You must capture and direct flowback emissions to a comple tion combustion device, except in conditions that may result in a fire hazard or explosion, or where high heat emissions from a completion combustion device may negatively impact tundra, permafrost or waterways. Completion combustion devices must be equipp ed with a reliable continuous ignition source over the duration of flowback. You must also comply with paragraphs (a)(4) and (b) through (e) of this section. (3) You must maintain records specified in §60.5420(c)(1)(iii) for wildcat , delineation and low p ressure gas wells. **§60.5380 What standards apply to centrifugal compressor affected facilities**  **?** You must comply with the standards in paragraphs (a) through (d) of this section for each centrifugal compressor affected facility.Page **12** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (a) (1) You must reduce VOC emissions from each centrifugal compressor wet seal fluid degassing system by 95 .0 percent or greater. (2) If you use a control device to reduce emissions, you must equip the wet seal fluid degassing system with a cover that meets the requirements of §60 .5411(b) , and that is connected through a closed vent system that meets the requirements of §60.5411(a) and routed to a control device that meets the conditions specified in §60.5412 (a), (b) and (c) . As an alternative to routing the closed vent system to a control device, you may route the closed vent system to a flow line , as defined in §60.5430
. (b) You must demonstrate initial compliance with the standards that apply to centrifugal compressor affected facilities as required by §60.5410 (b)

. (c) You mus t demonstrate continuous compliance with the standards that apply to centrifugal compressor affected facilities as required by §60.5415 (b)

. (d) You must perform the required notification, recordkeeping, and reporting as required by §60.5420. **§60.5385 Wha t standards apply to reciprocating compressor**  **affected facilities?**Page **13** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only You must comply with the standards in paragraphs (a) through (d) of this section for each reciprocating compressor affected facility. (a) You must replace the reciprocating compressor rod packing according to either paragraph (a)(1) or (2) of this section. (1) B efore the compressor has operated for 26,000 hours. The number of hours of operation must be continuously monitored beginning upon initial startup of your reciprocating compressor affected facility, or October 15, 2012, or the date of the most
recent reciprocating compressor rod packing replacement, whichever is later. (2) Prior to 36 months from the date of the most recent rod packing replacement, or 36 months from the date of sta rtup for a new reciprocating compressor for which the rod packing has not yet been replaced. (b) You must demonstrate initial compliance with standards that apply to reciprocating compressor affected facilities as required by §60.5410. (c) You must demon strate continuous compliance with standards that apply to reciprocating compressor affected facilities as required by §60.5415. (d) You must perform the required notification, recordkeeping, and reporting as required by §60.5420.Page **14** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only **§60.5390 What standards apply to pneumatic controller affected**  **facilities?** For each pneumatic controller affected facility you must comply with the VOC standards, based on natural gas as a surrogate for VOC, in either paragraph (b) (1) or (c) (1) of this section, as applicable. Pn eumatic controllers meeting the conditions in paragraph (a) of this section are exempt from this requirement. However, you must comply with the requirements in either paragraph (b)(2) or (c)(2), as applicable. (a) The requirements of paragraph (b) (1) or ( c) (1) of this section are not required if you determine that the use of a pneumatic controller affected facility with a bleed rate greater than 6 standard cubic feet per hour the applicable standard is required based on functional needs, including but not l imited to response time, safety and positive actuation. (b)(1) Each pneumatic controller affected facility at a natural gas processing plant must have a bleed rate of zero. (2) Each pneumatic controller affected facility at a natural gas processing pla nt must be tagged with the month and year of installation, reconstruction or modification, and identification information that allows traceability to the records for that pneumatic controlle r as required in §60.5420(c)(4)(iv).Page **15** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (c)(1) Each pneumatic contro ller affected facility constructed, modified or reconstructed on or after October 15, 2013, at a location between the wellhead and a natural gas processing plant or the point of custody transfer to an oil pipeline must have a bleed rate less than or equal to 6 standard cubic feet per hour. (2) Each pneumatic controller affected facility at a location between the wellhead and a natural gas processing plant or the point of custody transfer to an oil pipeline must be tagged with the month and year of installa tion, reconstruction or modification, and identification information that allows traceability to the records for that controlle r as required in §60.5420(c)(4)(iii). (d) You must demonstrate initial compliance with standards that apply to pneumatic control ler affected facilities as required by §60.5410. (e) You must demonstrate continuous compliance with standards that apply to pneumatic controller affected facilities as required by §60.5415. (f) You must perform the required notification, recordkeeping, and reporting as required by §60.5420, except that you are not required to submit the notifications specified in §60.5420(a) , except you are not required to submit the notifications in §60.5420 (a)
.Page **16** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only **§60.5395 What standards apply to storage vessel affected f**  **acilities?** Except as provided in paragraph (h) of this section, y ou must comply with the standards in this section for each storage vessel affected facility. (a) (1) If you are the owner or operator of a Group 1 storage vessel affected facility as define d in this subpart, you must comply with paragraph (b) of this section. (2) If you are the owner or operator of a Group 2 storage vessel affected facility as defined in this subpart , you must comply with paragraphs (c) through (g). (b) Requirements for Group 1 storage vessel affected facilities. (1) You must submit a notification identifying each Group 1 storage vessel, including its l ocation, by October 15, 2013. (2) On or after **[ INSERT DATE OF PUBLICATION IN THE FEDERAL** 
**REGISTER ]**  , if you have an event that could reasonably be expected to increase VOC emissions from your Group 1 storage vessel, you must comply with paragraphs (d) thr ough (g) of this section. For the purposes of this section, an event includes, but is not limited to, the examples specified in paragraphs (b)(2)(i) through (iv) of this section. (i) Routing a well to the storage vessel that was not previously routed to the storage vessel.Page **17** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (ii) Conducting hydraulic fracturing on a well routed to the storage vessel. (iii) Conducting hydraulic refracturing on a well routed to the storage vessel. (iv) Any other event that could increase the VOC emissions from the storage vessel affected facility. (c) Emissions determination . You must comply with paragraphs (c)(1) or (2) of this section. (1) For Group 2 storage vessels constructed, modified or reconstructed before April 15, 2014, you must determine the VOC emission rate no later than April 15, 2014, or 30 days after startup, whichever is later. To make this determination, yo u
must use any generally accepted model or calculation methodology

. If the VOC emission rate is determined to be equal to 6 tpy or greater, you must comply with paragraphs (d) through (g) of this section. (2) For Group 2 storage vessels constructed on or after April 15, 2014, you must determine the VOC emission rate using any generally accepted model or calculation methodology within 30 days after startup and minimize emissions to the extent practicable during the 30

- day period using good engineering practices through the period prior to installation of control. If the VOC emission rate is determined to be equal to 6 tpy orPage **18** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only greater, you must comply with paragraphs (d) through (g) of this section. (d) Y ou must comply with the requirements of paragraph ( d )(1) or ( 2) of this section

. (1) Reduce VOC emissions by 95.0 percent or greater by April 15, 2014 or within 60 days after startup , whichever is later

. (2) Maintain the VOC emissions from the storage vessel affected facility at less than 4 tpy without considering control, provided that you have been using a control device and have demonstrated that the VOC emissions have been below 4 tpy without co nsidering control for at least the 12 consecutive months immediately preceding the demonstration. You must determine the VOC emission rate each month using any generally accepted model or calculation method o logy and minim i ze emissions to the extent practicable during this period using good engineering practice

. Monthly calculations must be separated by at least 14 days

. (e) Control requirements

. ( 1 ) Except as required in paragraph (e)(2) of this section, if you use a control device (such as an enclosed combustion device or vapor recovery device) to reduce emissions from your storage vessel affected facility, you must equip the storage vessel with a cover that meets the requirements of §60.5411(b) and is con nected through a closedPage **19** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only vent system that meets the requirements of §60.5411 (c), and you
must route emissions to a control device that meets the conditions specified in §60.5412 (c) and (d). As an alternative to routing the closed vent system to a control d evice, you may route the closed vent system to a flow line, as defined in §60.5430
. If you route emissions to a flow line, you must equip the storage vessel with a cover that meets the requirements of §60.5411(b) and is connected through a closed vent s ystem that meets the requirements of §60.5411 (c )
.

( 2 ) If you use a floating roof to reduce emissions, you must meet the requirements of §60.112b(a)(1) or (2) and the relevant monitoring, inspection, recordkeeping, and reporting requirements in 40 CFR p art 60, subpart Kb. (f) Reserved. ( g ) Compliance, notification, recordkeeping, and reporting

. If you use a control device to reduce emissions or if you route your emissions to a flow line, you must comply with paragraphs (g)(1) and (2) of this section. (1) You must demonstrate initial compliance with standards as required by §60.5410 (h). ( 2 ) You mus t demonstrate continuous compliance with standards as required by §60.5415 (e)(3)
.Page **20** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( 3 ) You must perform the required notification, recordkeeping, and reporting as required by §60.5420. ( h ) Exempt ions

. This subpart does not apply to storage vessels subject to and controlled in accordance with the requirements for storage vessels in 40 CFR part 60, subpart Kb, 40 CFR part 63, subparts G, CC, HH, or WW. Except as provided in paragraph ( d ) of this s ection, y ou must comply with the standards in this section no later than October 15, 2013 for each storage vessel affected facility constructed, modified or reconstructed after August 23, 2011 , with VOC emissions equal to or greater than 6 tpy , as determined in paragraph (a) of this section. (a) Emissions determination

. (1) Well sites with no other wells in production

. For each storage vessel constructed, modified or reconstructed at a well site with no other wells in production, y ou must determine the VOC emission rate for each storage vessel affected facility using any generally accepted model or calculation methodology within 30 days after startup, and minimize emissions to the extent practicable during t he 30

- day period using good engineering practices

. For each storage vessel affected facility emitting more than 6 tpy VOC , you must reduce VOC emissions by 95.0 percent o r f greater within 60 days after startup .Page **21** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) Well sites with one or more wells already in production . For each storage vessel constructed, modified or reconstructed at a well site with one or more wells already in production, you must determine the VOC emission rat e for each storage vessel affected facility using any generally accepted model or calculation methodology upon startup

. For each storage vessel affected facility emitting more than 6 tpy VOC , you must reduce VOC emissions by 95.0 percent or greater upon st artup . ( b ) Control requirements

. ( 1 ) I f you use a control device (such as an enclosed combustion device or vapor recovery device) to reduce emissions, you must equip the storage vessel with a cover that meets the requirements of §60.5411(b) and is
connect ed through a closed vent system that meets the requirements of §60.5411 (a) to a control device that meets the conditions specified in §60.5412. ( 2 ) If you use a floating roof to reduce emissions, you must meet the requirements of §60.112b(a)(1) or (2) a nd the relevant monitoring, inspection, recordkeeping, and reporting requirements in 40 CFR part 60, subpart Kb. ( c ) Compliance, notification, recordkeeping, and reporting

. (1) You must demonstrate initial compliance with standards that apply to storage vessel affected facilities as required by §60.5410.Page **22** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( 2 ) You must demonstrate continuous compliance with standards that apply to storage vessel affected facilities as required by §60.5415. ( 3 ) You must perform the required notification, recordkeeping, and reporting as required by §60.5420

. ( d ) Exemptions

. This subpart does not apply to storage vessels subject to and controlled in accordance with the requirements for storage vessels in 40 CFR part 60, subpart Kb, or 40 CFR part 63, subparts G, CC, HH, WW , or HHH . **§60.5400 What equipment leak**  **standards apply to affected facilities at an onshore natural gas processing plant?**  This section applies to the group of all equipment, except compressors, within a process unit. (a) You must comply with the requirements of § §60.482

- 1a(a), (b), and (d), 60.482

- 2a, and 60.482

- 4a through 60.482

- 11a, except as provided in §60.5401. (b) You may elect to comply with the requirements of §§60.483

- 1a and 60.483

- 2a, as an alternative. (c) You may apply to the Administrator for permission to use an alternative means of emission limitation that achieves a reduction in emissions of VOC at least equivalent to that achieved by the controls re quired in this subpart according to the requirements of §60.5402 of this subpart.Page **23** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (d) You must comply with the provisions of §60.485a of this part except as provided in paragraph (f) of this section. (e) You must comply with the provisions of §§60. 486a and 60.487a of this part except as provided in §§60.5401, 60.5421, and 60.5422 of this part. (f) You must use the following provision instead of §60.485a(d)(1): Each piece of equipment is presumed to be in VOC service or in wet gas service unless an owner or operator demonstrates that the piece of equipment is not in VOC service or in wet gas service. For a piece of equipment to be considered not in VOC service, it must be determined that the VOC content can be reasonably expected never to exceed 1 0.0 percent by weight. For a piece of equipment to be considered in wet gas service, it must be determined that it contains or contacts the field gas before the extraction step in the process. For purposes of determining the percent VOC content of the proc ess fluid that is contained in or contacts a piece of equipment, procedures that conform to the methods described in ASTM E169

- 93, E168

- 92, or E260

- 96 (incorporated by reference as specified in §60.17) must be used. **§60.5401 What are the exceptions to the equipment leak**  **standards for affected facilities at onshore natural gas processing**  **plants?**Page **24** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (a) You may comply with the following exceptions to the provisions of §60.5400(a) and (b)

. (b)(1) Each pressure relief device in gas/vapor service may be mon itored quarterly and within 5 days after each pressure release to detect leaks by the methods specified in §60.485a(b) except as provided in §60.5400(c) and in paragraph (b)(4) of this section, and §60.482

- 4a(a) through (c) of subpart VVa. (2) If an in strument reading of 500 ppm or greater is measured, a leak is detected. (3)(i) When a leak is detected, it must be repaired as soon as practicable, but no later than 15 calendar days after it is detected, except as provided in §60.482

- 9a. (ii) A fi rst attempt at repair must be made no later than 5 calendar days after each leak is detected. (4)(i) Any pressure relief device that is located in a nonfractionating plant that is monitored only by non

- plant personnel may be monitored after a pressure release the next time the monitoring personnel are on

- site, instead of within 5 days as specified in paragraph (b)(1) of this section and §60.482

- 4a(b)(1) of subpart VVa. (ii) No pressure relief device described in paragraph (b)(4)(i) of this section must be allowed to operate for more than 30 days after a pressure release without monitoring.Page **25** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (c) Sampling connection systems are exempt from the requirements of §60.482

- 5a. (d) Pumps in light liquid service, valves in gas/vapor and light liquid se rvice, and pressure relief devices in gas/vapor service that are located at a nonfractionating plant that does not have the design capacity to process 283,200 standard cubic meters per day (scmd) (10 million standard cubic feet per day) or more of field ga s are exempt from the routine monitoring requirements of §§60.482

- 2a(a)(1) and 60.482

- 7a(a), and paragraph (b)(1) of this section. (e) Pumps in light liquid service, valves in gas/vapor and light liquid service, and pressure relief devices in gas/vapor service within a process unit that is located in the Alaskan North Slope are exempt from the routine monitoring requirements of §§60.482

- 2a(a)(1), 60.482

- 7a(a), and paragraph (b)(1) of this section. (f) An owner or operator may use the following provi sions instead of §60.485a(e): (1) Equipment is in heavy liquid service if the weight percent evaporated is 10 percent or less at 150 o C (302 o F) as determined by ASTM Method D86

- 96 (incorporated by reference as specified in §60.17). (2) Equipment is in light liquid service if the weight percent evaporated is greater than 10 percent at 150 o C (302 o F) asPage **26** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only determined by ASTM Method D86

- 96 (incorporated by reference as specified in §60.17). (g) An owner or operator may use the following provisions instead of §60.485a(b)(2): A calibration drift assessment shall be performed, at a minimum, at the end of each monitoring day. Check the instrument using the same calibration gas(es) that were used to calibrate the instrument before use. Follow the procedures spec ified in Method 21 of appendix A

- 7 of this part, Section 10.1, except do not adjust the meter readout to correspond to the calibration gas value. Record the instrument reading for each scale used as specified in §60.486a(e)(8). Divide these readings by the initial calibration values for each scale and multiply by 100 to express the calibration drift as a percentage. If any calibration drift assessment shows a negative drift of more than 10 percent from the initial calibration value, then all equipment monit ored since the last calibration with instrument readings below the appropriate leak definition and above the leak definition multiplied by (100 minus the percent of negative drift/divided by 100) must be re

- monitored. If any calibration drift assessment sh ows a positive drift of more than 10 percent from the initial calibration value, then, at the owner/operator’s discretion, all equipment since the last calibration with instrument readings above the appropriate leak definition and below the leak definition multiplied by (100 plusPage **27** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the percent of positive drift/divided by 100) may be re

monitored. **§60.5402 What are the alternative emission limitations for equipment leaks from onshore natural gas processing plants?**  (a) If, in the Administrator's judgment, an alternative means of emission limitation will achieve a reduction in VOC emissions at least equivalent to the reduction in VOC emissions achieved under any design, equipment, work practice or operational standard, the Administrator will publish, in the **Federal Register** , a notice permitting the use of that alternative means for the purpose of compliance with that standard. The notice may condition permission on requirements related to the operation and maintenance of the alternative

means. (b) Any no tice under paragraph (a) of this section must be published only after notice and an opportunity for a public hearing. (c) The Administrator will consider applications under this section from either owners or operators of affected facilities, or manufac turers of control equipment. (d) The Administrator will treat applications under this section according to the following criteria, except in cases where the Administrator concludes that other criteria are appropriate:Page **28** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (1) The applicant must collect , verify and submit test data, covering a period of at least 12 months, necessary to support the finding in paragraph (a) of this section. (2) If the applicant is an owner or operator of an affected facility, the applicant must commit in writing to ope rate and maintain the alternative means so as to achieve a reduction in VOC emissions at least equivalent to the reduction in VOC emissions achieved under the design, equipment, work practice or operational standard. **§60.5405 What standards apply to sweete ning units at onshore**  **natural gas processing plants?** (a) During the initial performance test required by §60.8(b), you must achieve at a minimum, an SO 2 emission reduction efficiency (Z i ) to be determined from Table 1 of this subpart based on the sulfur f eed rate (X) and the sulfur content of the acid gas (Y) of the affected facility. (b) After demonstrating compliance with the provisions of paragraph (a) of this section, you must achieve at a minimum, an
SO 2 emission reduction efficiency (Z c ) to be deter mined from Table 2 of this subpart based on the sulfur feed rate (X) and the sulfur content of the acid gas (Y) of the affected facility. **60.5406 What test methods and procedures must I use for my sweetening units affected facilities at onshore natural gas**  **processing plants?**Page **29** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (a) In conducting the performance tests required in §60.8, you must use the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in paragraph §60.8(b). (b) During a p erformance test required by §60.8, you must determine the minimum required reduction efficiencies (Z) of SO 2 emissions as required in §60.5405(a) and (b) as follows: (1) The average sulfur feed rate (X) must be computed as follows: X = K Q a Y Where: X = average sulfur feed rate, Mg/D (LT/D). Q a = average volumetric flow rate of acid gas from sweetening unit, dscm/day (dscf/day). Y = average H 2 S concentration in acid gas feed from sweetening unit, percent by volume, expressed as a decimal. K = (32 kg S/ kg

- mole)/((24.04 dscm/kg

- mole)(1000 kg S/Mg)) = 1.331 × 10 −3 Mg/dscm, for metric units = (32 lb S/lb

- mole)/((385.36 dscf/lb

- mole)(2240 lb S/long ton)) = 3.707 × 10 −5 long ton/dscf, for English units. (2) You must use the continuous readings from the process flowmeter to determine the average volumetric flow r ate (Q a ) in dscm/day (dscf/day) of the acid gas from the sweetening unit for each run. (3) You must use the Tutwiler procedure in §60.5408 or a chromatographic procedure following ASTM E260

- 96 (incorporated by reference as specified in §60.17) to determin e the H 2 S concentration in the acid gas feed from the sweetening unit (Y).Page **30** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only At least one sample per hour (at equally spaced intervals) must be taken during each 4

- hour run. The arithmetic mean of all samples must be the average H2S concentration (Y) on a dr y basis for the run. By multiplying the result from the Tutwiler procedure by 1.62 × 10 −3 , the units gr/100 scf are converted to volume percent. (4) Using the information from paragraphs (b)(1) and (b)(3) of this section, Tables 1 and 2 of this subpart mu st be used to determine the required initial (Z i ) and continuous (Z c ) reduction efficiencies of SO 2 emissions. (c) You must determine compliance with the SO 2 standards in §60.5405(a) or (b) as follows: (1) You must compute the emission reduction efficien cy (R) achieved by the sulfur recovery technology for each run using the following equation: R = ( 100 S ) / ( S + E ) (2) You must use the level indicators or manual soundings to measure the liquid sulfur accumulation rate in the product storage vessels . You must use readings taken at the beginning and end of each run, the tank geometry, sulfur dens ity at the storage temperature, and sample duration to determine the sulfur production rate (S) in kg/hr (lb/hr) for each run. (3) You must compute the emission rate of sulfur for each run as follows:Page **31** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only E = C e Q sd / K 1 Where: E = emission rate o f sulfur per run, kg/hr. C e = concentration of sulfur equivalent (SO 2+ reduced sulfur), g/dscm (lb/dscf). Q sd = volumetric flow rate of effluent gas, dscm/hr (dscf/hr). K 1 = conversion factor, 1000 g/kg (7000 gr/lb). (4) The concentration (C e ) of sulfur e quivalent must be the sum of the SO 2 and TRS concentrations, after being converted to sulfur equivalents. For each run and each of the test methods specified in this paragraph (c) of this section, you must use a sampling time of at least 4 hours. You must use Method 1 of appendix A to part 60 of this chapter to select the sampling site. The sampling point in the duct must be at the centroid of the cross

- section if the area is less than 5 m 2 (54 ft 2 ) or at a point no closer to the walls than 1 m (39 in) if the cross

sectional area is 5 m 2 or more, and the centroid is more than 1 m (39 in.) from the wall. (i) You must use Method 6 of appendix A to part 60 of this chapter to determine the SO 2 concentration. You must take eight samples of 20 minutes each at 30

- minute intervals. The arithmetic average must be the concentration for the run. The concentration must be multiplied by 0.5 × 10 −3 to convert the results to sulfur equivalent. (ii) You must use Method 15 of appendix A to part 60 of this chapter to determ ine the TRS concentration from reduction

-Page **32** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only type devices or where the oxygen content of the effluent gas is less than 1.0 percent by volume. The sampling rate must be at least 3 liters/min (0.1 ft 3 /min) to insure minimum residence time in the sample line. Yo u must take sixteen samples at 15

- minute intervals. The arithmetic average of all the samples must be the concentration for the run. The concentration in ppm reduced sulfur as sulfur must be multiplied by 1.333 × 10 −3 to convert the results to sulfur equivalent. (iii) You must use Method 16A or Method 15 of appendix A to part 60 of this chapter or ANSI/ASME PTC 19.10

- 1981, Part 10 (manual portion only) (incorporated by reference as specified in §60.17) to determine the reduced sulfur concentration from oxidation

- type devices or where the oxygen content of the effluent gas is greater than 1.0 percent by volume. You must take eight samples of 20 minutes each at 30

- minute intervals. The arithmetic average must be the co ncentration for the run. The concentration in ppm reduced sulfur as sulfur must be multiplied by 1.333 × 10 −3 to convert the results to sulfur equivalent. (iv) You must use Method 2 of appendix A to part 60 of this chapter to determine the volumetric flow rate of the effluent gas. A velocity traverse must be conducted at the beginning and end of each run. The arithmetic average of the two measurements must be used to calculate the volumetric flow rate (Q sd ) for thePage **33** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only run. For the determination of the effluent gas molecular weight, a single integrated sample over the 4

- hour period may be taken and analyzed or grab samples at 1

- hour intervals may be taken, analyzed, and averaged. For the moisture content, you must take two samples of at least 0.10 dscm (3.5 dscf) and 10 minutes at the beginning of the 4

- hour run and near the end of the time period. The arithmetic av erage of the two runs must be the moisture content for the run. **60.5407 What are the requirements for monitoring of emissions and operations from my sweetening unit affected facilities at**  **onshore natural gas processing plants?** (a) If your sweetening unit affected facility is located at an onshore natural gas processing plant and is subject to the provisions of §60.5405(a) or (b) you must install, calibrate, maintain, and operate monitoring devices or perform measurements to determine the following operati ons information on a daily basis: (1) The accumulation of sulfur product over each 24

- hour period. The monitoring method may incorporate the use of an instrument to measure and record the liquid sulfur production rate, or may be a procedure for measuring and recording the sulfur liquid levels in the storage vessels with a level indicator or by manual soundings, with subsequent calculation of the sulfur production rate based on the tank geometry, storedPage **34** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only sulfur density, and elapsed time between readings. The method must be designed to be accurate within ±2 percent of the 24

- hour sulfur accumulation. (2) The H 2 S concentration in the acid gas from the sweetening unit for each 24

- hour period. At least one sample per 24

- hour period must be collected and analyzed using the equation specified in §60.5406(b)(1). The Administrator may require you to demonstrate that the H 2 S concentration obtained from one or more samples over a 24

- hour period is within ±20 percent of the average of 12 samples collected at equally spa ced intervals during the 24

- hour period. In instances where the H2S concentration of a single sample is not within ±20 percent of the average of the 12 equally spaced samples, the Administrator may require a more frequent sampling schedule. (3) The averag e acid gas flow rate from the sweetening unit . You must install and operate a monitoring device to continuously measure the flow rate of acid gas. The monitoring device reading must be recorded at least once per hour during each 24

- hour period. The average acid gas flow rate must be computed from the individual readings. (4) The sulfur feed rate (X) . For each 24

- hour period, you must compute X using the equation specified in §60.5406(b)( 1 ). (5) The required sulfur dioxide emission reduction efficiency for the 24

- hour period

. You must use the sulfur feedPage **35** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only rate and the H 2 S concentration in the acid gas for the 24

- hour period, as applicable, to determine the required reduction efficiency in accordance with the provisions of §60.5405(b). (b) Where compliance i s achieved through the use of an oxidation control system or a reduction control system followed by a continually operated incineration device, you must install, calibrate, maintain, and operate monitoring devices and continuous emission monitors as follow s: (1) A continuous monitoring system to measure the total sulfur emission rate (E) of SO 2 in the gases discharged to the atmosphere . The SO 2 emission rate must be expressed in terms of equivalent sulfur mass flow rates (kg/hr (lb/hr)). The span of this m onitoring system must be set so that the equivalent emission limit of §60.5405(b) will be between 30 percent and 70 percent of the measurement range of the instrument system. (2) Except as provided in paragraph (b)(3) of this section: A monitoring device to measure the temperature of the gas leaving the combustion zone of the incinerator, if compliance with §60.5405(a) is achieved through the use of an oxidation control system or a reduction control system followed by a continually operated incineration de vice. The monitoring device must be certified by the manufacturer to be accurate to within ±1 percent of the temperature being measured.Page **3 6**  of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (3) When performance tests are conducted under the provision of §60.8 to demonstrate compliance with the standards und er §60.5405, the temperature of the gas leaving the incinerator combustion zone must be determined using the monitoring device. If the volumetric ratio of sulfur dioxide to sulfur dioxide plus total reduced sulfur (expressed as SO 2 ) in the gas leaving the incinerator is equal to or less than 0.98, then temperature monitoring may be used to demonstrate that sulfur dioxide emission monitoring is sufficient to determine total sulfur emissions. At all times during the operation of the facility, you must maintai n the average temperature of the gas leaving the combustion zone of the incinerator at or above the appropriate level determined during the most recent performance test to ensure the sulfur compound oxidation criteria are met. Operation at lower average te mperatures may be considered by the Administrator to be unacceptable operation and maintenance of the affected facility. You may request that the minimum incinerator temperature be reestablished by conducting new performance tests under §60.8. (4) Upon pr omulgation of a performance specification of continuous monitoring systems for total reduced sulfur compounds at sulfur recovery plants, you may, as an alternative to paragraph (b)(2) of this section, install, calibrate, maintain, and operate a continuous emission monitoring system for totalPage **37** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only reduced sulfur compounds as required in paragraph (d) of this section in addition to a sulfur dioxide emission monitoring system. The sum of the equivalent sulfur mass emission rates from the two monitoring systems must be used to compute the total sulfur emission rate (E). (c) Where compliance is achieved through the use of a reduction control system not followed by a continually operated incineration device, you must install, calibrate, maintain, and operate a continu ous monitoring system to measure the emission rate of reduced sulfur compounds as SO 2 equivalent in the gases discharged to the atmosphere. The SO 2 equivalent compound emission rate must be expressed in terms of equivalent sulfur mass flow rates (kg/hr (lb /hr)). The span of this monitoring system must be set so that the equivalent emission limit of §60.5405(b) will be between 30 and 70 percent of the measurement range of the system. This requirement becomes effective upon promulgation of a performance speci fication for continuous monitoring systems for total reduced sulfur compounds at sulfur recovery plants. (d) For those sources required to comply with paragraph (b) or (c) of this section, you must calculate the average sulfur emission reduction efficienc y achieved (R) for each 24

- hour clock internal. The 24

- hour interval may begin and end at any selected clock time, but must be consistent. You must computePage **38** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the 24

- hour average reduction efficiency (R) based on the 24

- hour average sulfur production rate (S) and sulfur emission rate (E), using the equation in §60.5406(c)(1). (1) You must use data obtained from the sulfur production rate monitoring device specified in paragraph (a) of this section to determine S. (2) You must use data obtained from the sulfu r emission rate monitoring systems specified in paragraphs (b) or (c) of this section to calculate a 24

- hour average for the sulfur emission rate (E). The monitoring system must provide at least one data point in each successive 15

- minute interval. You mus t use at least two data points to calculate each 1

- hour average. You must use a minimum of 18 1

- hour averages to compute each 24

- hour average. (e) In lieu of complying with paragraphs (b) or (c) of this section, those sources with a design capacity of les s than 152 Mg/D (150 LT/D) of H 2 S expressed as sulfur may calculate the sulfur emission reduction efficiency achieved for each 24

- hour period by:

R = K 2 S X Where: R = The sulfur dioxide removal efficiency achieved during the 24

- hour period, percent. K 2 = Conversion factor, 0.02400 Mg/D per kg/hr (0.01071 LT/D per lb/hr).Page **39** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only S = The sulfur production rate during the 24

- hour period, kg/hr (lb/hr)

. X = The sulfur feed rate in the acid gas, Mg/D (LT/D). (f) The monitoring devices required in paragraphs (b)(1), (b)(3) and (c) of this section must be calibrated at least annually according to the manufacturer's specifications, as required by §60.13(b)

. (g) The continuous emission monitoring systems required in paragraphs (b)(1), (b)(3), and (c) of this section must be subject to the emission monitoring requirements of §60.13 of the General Provisions. For conducting the continuous emission monitoring system performance evaluation required by §60.13(c), Performance Specification 2 of appendix B to part 60 of this chapter must apply, and Method 6 must be used for systems required by paragraph (b) of this section. **§60.5408 What is an o ptional procedure fo**  **r measuring hydrogen sulfide in acid gas**  **— Tutwiler Procedure?**  The Tutwiler procedure may be found in the Gas Engineers Handbook, Fuel Gas Engineering practices, The Industrial Press, 93 Worth Street, New York, NY, 1966, First Edition, Second Printing, page 6/25 (Docket A

- 80

- 20

- A, Entry II

- I

- 67). (a) When an instantaneous sample is desired and H2S concentration is ten grains per 1000 cubic foot or more, a 100 ml Tutwiler burette is used. For concentrations less than ten grains, a 500 ml Tutwiler burette and more dilute solutions arePage **40** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only used. In principle, this method consists of titrating hydrogen sulfide in a gas sample directly with a standard solution of iodine. (b) Apparatus . (See Figure 1 of this subpart) A 100 or 500 ml capacity Tutwiler burette, with t wo - way glass stopcock at bottom and three

- way stopcock at top which connect either with inlet tubulature or glass

- stoppered cylinder, 10 ml capacity, graduated in 0.1 ml subdivision; rubber tubing connecting burette with leveling bottle. (c) Reagents . (1) Iodine stock solution, 0.1N. Weight 12.7 g iodine, and 20 to 25 g cp potassium iodide for each liter of solution. Dissolve KI in as little water as necessary; dissolve iodine in concentrated KI solution, make up to proper volume, and store in glass

- stoppe red brown glass bottle. (2) Standard iodine solution, 1 ml=0.001771 g I. Transfer 33.7 ml of above 0.1N stock solution into a 250 ml volumetric flask; add water to mark and mix well. Then, for 100 ml sample of gas, 1 ml of standard iodine solution is equi valent to 100 grains H 2 S per cubic feet of gas. (3) Starch solution. Rub into a thin paste about one teaspoonful of wheat starch with a little water; pour into about a pint of boiling water; stir; let cool and decant off clear solution. Make fresh solutio n every few days.Page **41** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (d) Procedure

. Fill leveling bulb with starch solution. Raise (L), open cock (G), open (F) to (A), and close (F) when solutions starts to run out of gas inlet. Close (G). Purge gas sampling line and connect with (A). Lower (L) and open ( F) and (G). When liquid level is several ml past the 100 ml mark, close (G) and (F), and disconnect sampling tube. Open (G) and bring starch solution to 100 ml mark by raising (L); then close (G). Open (F) momentarily, to bring gas in burette to atmospheri c pressure, and close (F). Open (G), bring liquid level down to 10 ml mark by lowering (L). Close (G), clamp rubber tubing near (E) and disconnect it from burette. Rinse graduated cylinder with a standard iodine solution (0.00171 g I per ml); fill cylinder and record reading. Introduce successive small amounts of iodine thru (F); shake well after each addition; continue until a faint permanent blue color is obtained. Record reading; subtract from previous reading, and call difference D. (e) With every fres h stock of starch solution perform a blank test as follows: Introduce fresh starch solution into burette up to 100 ml mark. Close (F) and (G). Lower (L) and open (G). When liquid level reaches the 10 ml mark, close (G). With air in burette, titrate as duri ng a test and up to same end point. Call ml of iodine used C. Then, Grains H 2 S per 100 cubic foot of gas = 100(D

— C)Page **42** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (f) Greater sensitivity can be attained if a 500 ml capacity Tutwiler burette is used with a more dilute (0.001N) iodine solution. Concentr ations less than 1.0 grains per 100 cubic foot can be determined in this way. Usually, the starch

iodine end point is much less distinct, and a blank determination of end point, with H 2 S

- free gas or air, is required.Page **43** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Figure 1 . Tu twiler burette (lettered items mentioned in text).

§ **60.5410 How do I demonstrate initial compliance with the standards for my gas**  **well affected facility, my centrifugal**  **compressor affected facility, my reciprocating compressor**Page **44** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only **affected facility, my pneuma tic controller affected facility, my**  **storage vessel affected facility, and my equipment leaks and**  **sweetening unit affected facilities at onshore natural gas**  **processing plants?** You must determine initial compliance with the standards for each affected faci lity using the requirements in paragraphs (a) through ( g i ) of this section. The initial compliance period begins on October 15, 2012, or upon initial startup, whichever is later, and ends no later than one year after the initial startup date for your affec ted facility or no later than one year after October 15, 2012

. The initial compliance period may be less than one full year. (a) To achieve initial compliance with the standards for each well completion operation conducted at your gas well affected facil ity you must comply with paragraphs (a)(1) through (a)(4) of this section. (1) You must submit the notification required in §60.5420(a)(2). (2) You must submit the initial annual report for your well affected facility as required in §60.5420(b). (3) You must maintain a log of records as specified in §60.5420(c)(1) (i) through (iv) for each well completion operation conducted during the initial compliance period.Page **45** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (4) For each gas well affected facility subject to both §60.5375(a)(1) and (3), as an alterna tive to retaining the records specified in §60.5420(c)(1) (i) through (iv) , you must
may maintain records of one or more digital photographs with the date the photograph was taken and the latitude and longitude of the well site imbedded within or stored wit h the digital file showing the equipment for storing or re

- injecting recovered liquid, equipment for routing recovered gas to the gas flow line and the completion combustion device (if applicable) connected to and operating at each gas well completion oper ation that occurred during the initial compliance period. As an alternative to imbedded latitude and longitude within the digital photograph, the digital photograph may consist of a photograph of the equipment connected and operating at each well completio n operation with a photograph of a separately operating GIS device within the same digital picture, provided the latitude and longitude output of the GIS unit can be clearly read in the digital photograph. (b) (1) To achieve initial compliance with standard s for your centrifugal compressor affected facility you must reduce
VOC emissions from each centrifugal compressor wet seal fluid degassing system by 95 .0 percent or greater as required by §60.5380 and as demonstrated by the requirements of §60.5413

.Page **46** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) If you use a control device to reduce emissions, you must equip the wet seal fluid degassing system with a cover that meets the requirements of §60.5411(b) that and is connected through a closed vent system that meets the requirements of §60.5411(a) and is routed to a control device that meets the conditions specified in §60.5412 (a), (b) and (c) . As an alternative to routing the closed vent system to a control device, you may route the closed vent system to a flow line , as defined in §60.5430

. ( 3 ) You must conduct an initial performance test as required in §60.5413 within 180 days after initial startup or by October 15, 2012, whichever is later , and you must comply with the continuous compliance requirements in §60.5415( b ) (1) through (3)
. ( 4 ) You must con duct the initial inspections required in §60.5416 (a) and (b)

. (5 ) You must install and operate the continuous parameter monitoring systems in accordance with §60.5417 (a) through (g) , as applicable

. (6) You must submit the notifications required in 60.7( a)(1), (3) , and (4). (7) You must submit the initial annual report for your centrifugal compressor affected facility as required inPage **47** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only §60.5420(b) (3) for each centrifugal compressor affected facility

. (8) You must maintain the records as specified in §60 .5420(c)( 3 2 ). (c) To achieve initial compliance with the standards for each reciprocating compressor affected facility you must comply with paragraphs (c)(1) through ( 4 ) of this section. (1) During the initial compliance period, you must continuously mon itor the number of hours of operation or track the number of months since the last rod packing replacement

. (2) You must submit the notifications required in 60.7(a)(1), (3) , and (4). ( 3 ) You must submit the initial annual report for your reciprocating compressor as required in §60.5420(b). (4) You must maintain the records as specified in §60.5420(c)(3) for each reciprocating compressor affected facility. (d) To achieve initial compliance with emission standards for your pneumatic controller affected facility you must comply with the requirements specified in paragraphs (d)(1) through ( 6 ) of this section , as applicable

. (1) If applicable, Y y ou have must demonstrate d initial compliance by maintaining records as specified in §60.5420(c)(4)(ii) of your determination that the use of aPage **48** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only pneumatic controller affected facility with a bleed rate greater than 6 standard cubic feet of gas per hour is required as specified in §60.5 3 90(a). (2) You own or operate a pneumatic controller affected facility located at a natural gas processing plant and your pneumatic controller is driven by a gas other than by use of natural gas and therefore emits zero natural gas. (3) You own or operate a pneumatic controller affected facility located between the wellhead and a na tural gas processing plant and the manufacturer’s design specifications indicate that the controller emits less than or equal to 6 standard cubic feet of gas per hour. (4) You must tag each new pneumatic controller affected facility according to the requi rements of §60.5390( b )(2) or (c)(2)
. (5) You must include the information in paragraph (d)(1) of this section and a listing of the pneumatic controller affected facilities specified in paragraphs (d)(2) and (3) of this section in the initial annual report submitted for your pneumatic controller affected facilities constructed, modified or reconstructed during the period covered by the annual report according to the requirements of §60.5420(b). (6) You must maintain the records as specified in §60.5420(c)( 4) for each pneumatic controller affected facility.Page **49** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (e) [Reserved] To achieve initial compliance with the emission standards for your storage vessel affected facility you must comply with paragraphs (e)(1) through ( 9 ) of this section. (1) You have determi ned the VOC emission rate within 30 days after startup for storage vessels constructed, modified or reconstructed at well sites with no other wells in production, and y ou must use good engineering practices to minimize emissions during the 30

- day period

. (2) You must determine the VOC emission rate upon startup for storage vessels constructed, modified or reconstructed at well sites with one or more wells already in production. ( 2 3 ) For storage vessel affected facilities emitting more than 6 tpy VOC , you must reduce VOC emissions by 95.0 percent or greater within 60 days after startup for storage vessels constructed, modified or reconstructed at well sites with no other wells in production, or upon startup for storage vessels constructed, modified or reconstructed at well sites with one or more wells already in production. ( 4) I f you use a control device to reduce emissions, y ou must equip the storage vessel with a cover that meets the requirements of §60.5411(b) and is connected through a closed vent system that meets the requirements of §60.5411 (a) to a control device that meets the conditions specified in §60.5412 within 60 days after startup for storage vesselsPage **50** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only constructed, modified or reconstructed at well sites with no other wells in productio n, or upon startup for storage vessels constructed, modified or reconstructed at well sites with one or more wells already in production

. ( 5 ) You must conduct an initial performance test as required in §60.5413 within 180 days after initial startup or wit hin 180 days of October 15, 2013 , whichever is later, and must conduct the compliance demonstration in §60.5415( b ). ( 6 ) You must conduct the initial inspectio ns required in §60.5416. ( 7 ) You must install and operate continuous parameter monitoring systems in accordance with §60.5417. ( 8 ) You must submit the information in paragraphs (e)(1) through ( 7 ) of this section in the initial annual report as required in §60.5420(b). (9) You must maintain the records as specified in §60.5420(c)(5) for each storage vessel affected facility. (f) For affected facilities at onshore natural gas processing plants, initial compliance with the VOC requirements is demonstrat ed if you are in compliance with the requirements of §60.5400. (g) For sweetening unit affected facilities at onshore natural gas processing plants, initial compliance isPage **51** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only demonstrated according to paragraphs (g)(1) through (3) of this section. (1) To det ermine compliance with the standards for SO 2 specified in §60.5405(a), during the initial performance test as required by §60.8, the minimum required sulfur dioxide emission reduction efficiency (Z i ) is compared to the emission reduction efficiency (R) ach ieved by the sulfur recovery technology as specified in paragraphs (g)(1)(i) and (ii) of this section. (i) If R ≥ Z i , your affected facility is in compliance. (ii) If R < Z i , your affected facility is not in compliance. (2) The emission reduction effici ency (R) achieved by the sulfur reduction technology must be determined using the procedures in §60.5406(c)(1). (3) You have submitted the results of paragraphs (g)(1) and (2) of this section in the initial annual report submitted for your sweetening unit affected facilities at onshore natural gas processing plants. (h) For each storage vessel affected facility that is subject to §60.5395(d) , you must comply with paragraphs (h)(1) through (5) of this section. (1) Y ou must determine the VOC emissi on rate within 30 days after startup. You must use good engineering practices to minimize emissions during the 30

- day period

.Page **52** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( 2 ) You must reduce VOC emissions by 95.0 percent or greater within 60 days after startup or by April 15, 2014, whichever is late r . (3) If you use a control device to reduce emissions, or if you route emissions to a flow line, you must demonstrate initial compliance by meeting the requirements in paragraphs (h)(3)(i) and (ii) of this section. For a Group 1 storage vessel affecte d facility, you must demonstrate initial compliance within 30 days after an event (as provided in §60.5395(b)) or by April 15, 2014, whichever is later. For a Group 2 storage vessel affected facility, you must demonstrate initial compliance within 60 days after startup or by April 15, 2014, whichever is later. (i) Y ou must equip the storage vessel with a cove r that meets the requirements of §60.5411( b ) and is connected through a closed vent system that meets the requirements of §60.5411 (c). (ii) You must route the closed vent system to a control device that meets the conditions specified in §60.5412 (c) and (d) or to a flow line, as defined in §60.5430

. ( 4 ) You must submit the information required for your storage vessel affected facility in paragraphs ( h )(4)(i) through ( iii ) of this section in the initial annual report required in §60.5420(b).Page **53** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i ) The results of the emissions determination conducted under § 60.5395 (b) or (c), as applicable, and the methodology used to determine emissions. (ii) A statement that you have met the requirements of paragraph (h)(2) of this section. (iii) A stateme nt that you have met the emissions standards in §60.5395(d). ( 5 ) You must maintain the records required for your storage vessel affected facility, as specified in §60.5420(c)(5) for each sto rage vessel affected facility. (i) For each Group 1 storage vessel , you must submit a notification identify ing each storage vessel , including its location by October 15, 2013

. If you have an event that results in VOC emissions from the Group 1 storage ves sel equal to or greater than 6 tpy after **[INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER]**  , as specified in §60.5395(b), you must comply with paragraph (h) of this section

. **§60.5411 What additional**  **requirements must I meet to determine**  **initial compliance for**  **my covers and**  **closed vent systems routing materials from storage vessels**  **and centrifugal compressor wet seal degassing systems**  **?** You must meet the applicable requirements of this section for each cover and closed vent sy stem used to comply with thePage **54** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only emission standards for your storage vessel or centrifugal
compressor affected facility. (a) Closed vent system requirements for centrifugal compressor wet seal degassing systems . (1) You must design the closed vent system to r oute all gases, vapors, and fumes emitted from the material in the storage vessel or wet seal fluid degassing system to a control device that meets the requirements specified in §60.5412 (a) through (c)

. (2) You must design and operate the closed vent sys tem with no detectable emissions as demonstrated by §60.5416(b)

. (3) You must meet the requirements specified in paragraphs (a)(3)(i) and (ii) of this section if the closed vent system contains one or more bypass devices that could be used to divert all o r a portion of the gases, vapors, or fumes from entering the control device. (i) Except as provided in paragraph (a)(3)(ii) of this section, you must comply with either paragraph (a)(3)(i)(A) or (B) of this section for each bypass device. (A) You must pr operly install, calibrate, maintain, and operate a flow indicator at the inlet to the bypass device that could divert the stream away from the control device or flow line to the atmosphere that is capable of taking periodic readings as specified in §60.541 6(a)(4) and sounds an alarm when the bypass device is open such that the stream is being, orPage **55** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only could be, diverted away from the control device to the atmosphere. (B) You must secure the bypass device valve installed at the inlet to the bypass device in the non - diverting position using a car

- seal or a lock

- and

- key type configuration. (ii) Low leg drains, high point bleeds, analyzer vents,
open - ended valves or lines, and safety devices are not subject to the requirements of paragraph (a)(3)(i) of this section

. (b) Cover requirements for storage vessels and centrifugal compressor wet seal degassing systems . (1) The cover and all openings on the cover ( e.g. , access hatches, sampling ports, pressure relief valves and gauge wells) shall form a continuous barrier over the entire surface area of the liquid in the storage vessel or wet seal fluid degassing system

. (2) Each cover opening shall be secured in a closed, sealed position ( e.g. , covered by a gasketed lid or cap) whenever material is in the unit on which the cover is installed except during those times when it is necessary to use an opening as follows: (i) To add material to, or remove material from the unit (this includes openings necessary to equalize or balance the internal pressure of the un it following changes in the level of the material in the unit); (ii) To inspect or sample the material in the unit;Page **56** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iii) To inspect, maintain, repair, or replace equipment located inside the unit; or (iv) To vent liquids, gases, or fumes from the unit through a closed

- vent system to a control device designed and operated in accordance with the requirements of paragraph (a) of this section or to a flow line, as defined in §60.5430
. (3) Each storage vessel thief hatch shall be weighted and properly seat ed. You must select gasket material for the hatch based on composition of the fluid in the storage vessel and weather conditions. ( c ) Closed vent system requirements for storage vessel affected facilit ies using a control device or routing emiss ions to a flow line

. (1) You must design the closed vent system to route all gases, vapors, and fumes emitted from the material in the storage vessel to a control device that meets the requirements specified in §60.5412 (c) and (d) , or to a flow line, as defined in §60.5430

. (2) You must design and operate the closed vent syst em with no detectable emissions , as determined using olfactory, visual and auditory inspections. (3) You must meet the requirements specified in paragraphs ( c )(3)(i) and (i i) of this section if the closed vent system contains one or more bypass devices that could be used to divertPage **57** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only all or a portion of the gases, vapors, or fumes from entering the control device or to a flow line, as defined in §60.5430

. (i) Except as provid ed in paragraph ( c )(3)(ii) of this section, you must comply with either paragraph ( c )(3)(i)(A) or (B) of this section for each bypass device. (A) You must properly install, calibrate, maintain, and operate a flow indicator at the inlet to the bypass devic e that could divert the stream away from the control device or flow line to the atmosphere that sounds an alarm when the bypass device is open such that the stream is being, or could be, diverted away from the control device or flow line to the atmosphere. (B) You must secure the bypass device valve installed at the inlet to the bypass device in the non

- diverting position using a car

- seal or a lock

- and

- key type configuration. (ii) Low leg drains, high point bleeds, analyzer vents,
open - ended valves or lin es, and safety devices are not subject
to the requirements of paragraph (c )(3)(i) of this section. **§60.5412 What additional**  **requirements must I meet for determining initial compliance with**  **control devices used to comply with the emission standards f**  **or my storage vessel**  **or centrifugal compressor**  **affected facility?** You must meet the applicable requirements of this section for each control device used to comply with the emissionPage **58** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only standards for your storage vessel or centrifugal compressor affected facil ity

. (a) If you use a Each control device used to meet the emission reduction standard in §60.5380(a)(1) for your centrifugal compressor affected facility or §60.5395( a )(1) or (2) for your storage vessel , y ou must be use one of the control devices specif ied in paragraphs (a)(1) through (3) of this section. You install ed according to paragraphs ( a )(1) through ( 3 ) of this section

. m ust demonstrate that the control device achieves the performance requirements using the performance test methods and procedur es specified in §60.5413. As an alternative, for a centrifugal compressor affected facility , you may install a control device model tested under §60.5413(d), which meets the criteria in §60.5413(d)(11) and §60.5413(e). (1) E ach You must design and operat e an enclosed combustion device ( e.g. , thermal vapor incinerator, catalytic vapor incinerator, boiler, or process heater) must be designed and operated in accordance with one of the performance requirements specified in paragraphs (a)(1)(i) through (iv) o f this section.

(i) You must reduce the mass content of VOC in the gases vented to the device by 95.0 percent by weight or greater as determined in accordance with the requirements of §60.5413.Page **59** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (ii) You must reduce the concentration of TOC in the exhaus t gases at the outlet to the device to a level equal to or less than 20 parts per million by volume on a dry basis corrected to 3 percent oxygen as determined in accordance with the requirements of §60.5413. (iii) You must operate at a minimum temperature of 760°C for a control device that can demonstrate a uniform combustion zone temperature during the performance test conducted under §60.5413. (iv) If a boiler or process heater is used as the control device, then you must introduce the vent stream into the flame zone of the boiler or process heater. (2) You must design and operate a Each vapor recovery device ( e.g. , carbon adsorption system or condenser) or other

non - destructive control device must be designed and operated to reduce the mass content of VOC in the gases vented to the device by 95.0 percent by weight or greater as determined in accordance with the requirements of §60.5413. The vapor recovery device As an alternative to the performance testing requirements, you may demonstrate initial compl iance by conducting a must meet the design analysis for vapor recovery devices according to the requirements of §60.5413(c)

.Page **60** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (3) You must design and operate a flare in accordance with the requirements of §60.5413

. (b) You must operate each control dev ice installed on your centrifugal compressor affected facility in accordance with the requirements specified in paragraphs (b)(1) and (2) of this section. (1) You must operate each control device used to comply with this subpart at all times when gases, vapors, and fumes are vented from the storage vessel affected facility, as required under §60.5395, or wet seal fluid degassing system affected facility , as required under §60.5380 (a) , through the closed vent system to the control device. You may vent more than one affected facility to a control device used to comply with this subpart. (2) For each control device monitored in accordance with the requirements of §60.5417 ( a ) through (g) , you must demonstrate compliance according to the requirements of §60.54 15( e b ) (2) , as applicable. (c) For each carbon adsorption system used as a control device to meet the requirements of paragraph (a) (2) or ( d )( 2 ) of this section, you must manage the carbon in accordance with the requirements specified in paragraphs (c)(1) or (2) of this section.Page **61** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (1) Following the initial startup of the control device, you must replace all carbon in the control device with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established acco rding to §60.5413(c)(2) or (3) or according to the design analysis in paragraph ( d )( 2 ) of this section, for the carbon adsorption system. You must maintain records identifying the schedule for replacement and records of each carbon replacement as required in § 60.5420(c)( 6 10 ) and ( 13 )
. (2) You must either regenerate, reactivate, or burn the spent carbon removed from the carbon adsorption system in one of the units specified in paragraphs (c)(2)(i) through (vii) of this section. (i) Regenerate or reactivat e the spent carbon in a thermal treatment unit for which you have been issued a final permit under 40 CFR part 270 that implements the requirements of 40 CFR part 264, subpart X. (ii) Regenerate or reactivate the spent carbon in a thermal treatment unit e quipped with and operating air emission controls in accordance with this section. (iii) Regenerate or reactivate the spent carbon in a thermal treatment unit equipped with and operating organic air emission controls in accordance with an emissions standar d for VOC under another subpart in 40 CFR part 60 or this part.Page **62** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iv) Burn the spent carbon in a hazardous waste incinerator for which the owner or operator has been issued a final permit under 40 CFR part 270 that implements the requirements of 40 CFR
par t 264, subpart O. (v) Burn the spent carbon in a hazardous waste incinerator which you have designed and operated in accordance with the requirements of 40 CFR part 265, subpart O. (vi) Burn the spent carbon in a boiler or industrial furnace for which yo u have been issued a final permit under 40 CFR part 270 that implements the requirements of 40 CFR part 266, subpart H. (vii) Burn the spent carbon in a boiler or industrial furnace that you have designed and operated in accordance with the interim status requirements of 40 CFR part 266, subpart H. ( d ) Each control device used to meet the emission reduction standard in §60.5395( d ) for your storage vessel affected facility , must be installed according to paragraphs (d)(1) through (3) of this section , as applicable . As an alternative, you may install a control device model tested under §60.5413(d), which meets the criteria in §60.5413(d)(11) and §60.5413(e). (1) Each enclosed combustion device ( e.g. , thermal vapor incinerator, catalytic vapor incine rator, boiler, or process heater) must be designed to reduce the mass content of VOC emissions by 95 .0 percent or greater. You must follow thePage **63** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only requirements in paragraphs (d)(1)(i) through (v) of this section. (i) Ensure that each enclosed combustion device is maintained in a leak free condition

.

( i i ) Install and operate a continuous burning pilot flame

. ( iii ) Operate the enclosed combustion device with no visible emissions , except for periods not to exceed a total of one minute during any 15 minute period. A vi sible emissions test using section 11 of EPA Method 22, 40 CFR part 60, Appendix A, must be performed at least once every calendar month , separated by at least 15 days between each test

. The observation period shall be 15 minutes. Devices failing the visib le emissions test must follow manufacturer’s repair instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All inspection, repair and maintena nce activities for each unit must be recorded in a maintenance and repair log and must be available on

- site for inspection. Following return to operation from maintenance or repair activity, each device must pass a Method 22 , 40 CFR part 60, Appendix A, v isual observation as described in this paragraph. (2) Each vapor recovery device ( e.g. , carbon adsorption system or condenser) or other non

- destructive control devicePage **64** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only must be designed and operated to reduce the mass content of VOC in the gases vented to t he device by 95.0 percent by weight or greater . A carbon replacement schedule must be included in the design of the carbon adsorption system. ( 3 ) You must operate each control device used to comply with this subpart at all times when gases, vapors, and fum es are vented from the storage vessel affected facility through the closed vent system to the control device. You may vent more than

one affected facility to a control device used to comply with this subpart. **§60 .5413 What are the performance testing procedures for control**  **devices used to demonstrate compliance at my storage vessel or**  **centrifugal compressor affected facility?**  This section applies to the performance testing of control devices used to demonstrate c ompliance with the emissions standards for your storage vessel or centrifugal compressor affected facility. You must demonstrate that a control device achieves the performance requirements of §60.5412(a) using the performance test methods and procedures sp ecified in paragraph (b) of this section. For condensers, you may use a design analysis as specified in paragraph (c) of this section in lieu of complying with paragraph (b) of this section. In addition, this section contains the requirements for enclosed combustion device performance tests conducted by the manufacturerPage **65** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only applicable to both storage vessel and centrifugal compressor affected facilities

. (a) Performance test exemptions . You are exempt from the requirements to conduct performance tests and de sign analyses if you use any of the control devices described in paragraphs (a)(1) through (7) of this section. (1) A flare that is designed and operated in accordance with §60.18(b). You must conduct the compliance determination using Method 22 at 40 CFR part 60, appendix A

- 7, to determine visible emissions. (2) A boiler or process heater with a design heat input capacity of 44 megawatts or greater. (3) A boiler or process heater into which the vent stream is introduced with the primary fuel or is used as the primary fuel. (4) A boiler or process heater burning hazardous waste for which you have either been issued a final permit under 40 CFR part 270 and comply with the requirements of 40 CFR part 266, subpart H; or you have certified compliance with t he interim status requirements of 40 CFR part 266, subpart H. (5) A hazardous waste incinerator for which you have been issued a final permit under 40 CFR part 270 and comply with the requirements of 40 CFR part 264, subpart O; or you havePage **66** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only certified compl iance with the interim status requirements of 40 CFR part 265, subpart O. (6) A performance test is waived in accordance with §60.8(b). (7) A control device whose model that can be demonstrated to meet the performance requirements of §60.5412(a) through a performance test conducted by the manufacturer, as specified in paragraph (d) of this section. (b) Test methods and procedures . You must use the test methods and procedures specified in paragraphs (b)(1) through(5) of this section, as applicable, for eac h performance test conducted to demonstrate that a control device meets the requirements of §60.5412(a). You must conduct the initial and periodic performance tests according to the schedule specified in paragraph (b)(5) of this section. (1) You must use Method 1 or 1A at 40 CFR part 60, appendix

A

- 1, as appropriate, to select the sampling sites specified in paragraphs (b)(1)(i) and (ii) of this section. Any references to particulate mentioned in Methods 1 and 1A do not apply to this section. (i) Samplin g sites must be located at the inlet of the first control device, and at the outlet of the final control device, to determine compliance with the control device percent reduction requirement specified in §60.5412(a)(1)(i) or (a)(2).Page **67** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (ii) The sampling site must be located at the outlet of the combustion device to determine compliance with the enclosed combustion device total TOC concentration limit specified in §60.5412(a)(1)(ii). (2) You must determine the gas volumetric flowrate using Method 2, 2A, 2C, o r 2D at 40 CFR part 60, appendix A

- 2, as appropriate. (3) To determine compliance with the control device percent reduction performance requirement in §60.5412(a)(1)(i) or (a)(2), you must use Method 25A at 40 CFR part 60, appendix A

- 7. You must use the p rocedures in paragraphs (b)(3)(i) through (iv) of this section to calculate percent reduction efficiency. (i) For each run, you must take either an integrated sample or a minimum of four grab samples per hour. If grab sampling is used, then the samples mu st be taken at approximately equal intervals in time, such as 15

- minute intervals during the run. (ii) You must compute the mass rate of TOC (minus methane and ethane) using the equations and procedures specified in paragraphs (b)(3)(ii)(A) and ( B ) of thi s section. ( A ) You must use the following equations:

E i = K 2 � � C ij M ij n
j = 1 � Q iPage **68** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only E o = K 2 � � C oj M oj n
j = 1 � Q o

Where:
E i , E o = Mass rate of TOC (minus methane and ethane) at the inlet and outlet of the control device, respectively, dry basis, kilogram per hour.

K 2 = Constant, 2.494 × 10 −6 (parts per million) (gram

- mole per standard cubic meter) (kilogram/gram) (minute/hour), where standard temperature (gram

- mole per standard cubic meter) is 20°C.
C ij , C oj = Concentration of sample component j of the gas stream at the inlet and outlet of the control device, respectively, dry basis, parts per million by volume.

M ij , M oj = Molecular weight of sample component j of the gas stream at the inlet and outlet of the control device, respectively, gram/gram

- mole. Q i , Q o = Flowrate of gas stream at the inlet and outlet of the control device, respectively, dry standard cubic meter per minute.

n = Number of components in sample. ( B ) When calculating the TOC mass rate, you must sum all organic compounds (minus methane and ethane) measured by MethodPage **69** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only 25A at 40 CFR part 60, appendix A

- 7 using the equations in paragraph (b)(3)(ii)( A) of this section. (iii) You must calculate the percent reduction in TOC (minus methane and ethane) as follows:

R cd = E i − E o E i ∗ 100%

Where:
R cd = Control efficiency of control device, percent.

E i = Mass rate of TOC (minus methane and ethane) at the inlet to the control device as calculated under paragraph (b)(3)(ii) of this section, kilograms TO C per hour or kilograms HAP per hour.
E o = Mass rate of TOC (minus methane and ethane) at the outlet of the control device, as calculated under paragraph (b)(3)(ii) of this section, kilograms TOC per hour per hour.

(iv) If the vent stream entering a boil er or process heater with a design capacity less than 44 megawatts is introduced with the combustion air or as a secondary fuel, you must determine the weight

- percent reduction of total TOC (minus methane and ethane) across the device by comparing the TOC (minus methane and ethane) in all combusted vent streams and primary and secondary fuels with the TOC (minus methane and ethane) exiting the device, respectively.Page **70** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (4) You must use Method 25A at 40 CFR part 60, appendix A

- 7 to measure TOC (minus methane an d ethane) to determine compliance with the enclosed combustion device total VOC concentration limit specified in §60.5412(a)(1)(ii). You must calculate parts per million by volume concentration and correct to 3 percent oxygen, using the procedures in parag raphs (b)(4)(i) through (iii) of this section. (i) For each run, you must take either an integrated sample or a minimum of four grab samples per hour. If grab sampling is used, then the samples must be taken at approximately equal intervals in time, such as 15

- minute intervals during the run. (ii) You must calculate the TOC concentration for each run as follows:

C TOC = � � ∑ C ji n j = i �

x x

i = 1

Where:
C TOC = Concentration of total organic compounds minus methane and ethane, dry basis, parts per million by volume.
C ji = Concentration of sample component j of sample i, dry basis, parts per million by volume.

n = Number of components in the sample.

x = Number of samples in the sample run.Page **71** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iii) You must correct the TOC concentration to 3 percent oxygen as specified in paragraphs (b)(4)(iii)(A) and (B) of this section. ( A ) You must use the emission rate correction factor for excess air, integrated sampling and analysis procedures of Method 3A or 3B at 40 CFR part 60, appendix A , ASTM D6522

- 00 (Reapproved 2005), or ANSI/ASME PTC 19.10

- 1981, Part 10 (manual portion only) (incorporated by reference as s pecified in §60.17) to determine the oxygen concentration. The samples must be taken during the same time that the samples are taken for determining TOC concentration. ( B ) You must correct the TOC concentration for percent
oxygen as follows:

C c = C m � 17

. 9 20

. 9

− % O 2 d �

Where:
C c = TOC concentration corrected to 3 percent oxygen, dry basis, parts per million by volume.
C m = TOC concentration, dry basis, parts per million by volume. %O 2d = Concentration of oxygen, dry basis, percent by volume.Page **72** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (5) You must conduct performance tests according to the schedule specified in paragraphs (b)(5)(i) and (ii) of this section. (i) You must conduct an initial performance test within 180 days after initial startup for your affected facility. You must submi t the performance test results as required in
§ 60.5420(b)(7)

. (ii) You must conduct periodic performance tests for all control devices required to conduct initial performance tests except as specified in paragraphs (b)(5)(ii)(A) and (B) of this section. Y ou must conduct the first periodic performance test no later than 60 months after the initial performance test required in paragraph (b)(5)(i) of this section. You must conduct subsequent periodic performance tests at intervals no longer than 60 months fol lowing the previous periodic performance test or whenever you desire to establish a new operating limit. You must submit the periodic performance test results as specified in § 60.5420(b)(7) . Combustion control devices meeting the criteria in either paragra ph (b)(5)(ii)(A) or (B) of this section are not required to conduct periodic performance tests. (A) A control device whose model is tested under, and meets the criteria of paragraph (d) of this section. (B) A combustion control device tested under paragr aph (b) of this section that meets the outlet TOC performance levelPage **73** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only specified in §60.5412(a)(1)(ii) and that establishes a correlation between firebox or combustion chamber temperature and the TOC performance level. (c) Control device design analysis to m eet the requirements of §60.5412(a) . (1) For a condenser , the design analysis must include an analysis of the vent stream composition, constituent concentrations, flowrate, relative humidity, and temperature, and must establish the design outlet organic co mpound concentration level, design average temperature of the condenser exhaust vent stream, and the design average temperatures of the coolant fluid at the condenser inlet and outlet. (2) For a regenerable carbon adsorption system, the design analysis sh all include the vent stream composition, constituent concentrations, flowrate, relative humidity, and temperature, and shall establish the design exhaust vent stream organic compound concentration level, adsorption cycle time, number and capacity of carbon beds, type and working capacity of activated carbon used for the carbon beds, design total regeneration stream flow over the period of each complete carbon bed regeneration cycle, design carbon bed temperature after regeneration, design carbon bed regener ation time, and design service life of the carbon. (3) For a nonregenerable carbon adsorption system, such as a carbon canister, the design analysis shall include the ventPage **74** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only stream composition, constituent concentrations, flowrate, relative humidity, and te mperature, and shall establish the design exhaust vent stream organic compound concentration level, capacity of the carbon bed, type and working capacity of activated carbon used for the carbon bed, and design carbon replacement interval based on the total carbon working capacity of the control device and source operating schedule. In addition, these systems will incorporate dual carbon canisters in case of emission breakthrough occurring in one canister. ( 4 ) If you and the Administrator do not agree on a demonstration of control device performance using a design analysis, then you must perform a performance test in accordance with the requirements of paragraph (b) of this section to resolve the disagreement. The Administrator may choose to have an authoriz ed representative observe the performance test. (d) Performance testing for combustion control devices

– manufacturers’ performance test

. (1) This paragraph applies to the performance testing of a combustion control device conducted by the device manufa cturer. The manufacturer must demonstrate that a specific model of control device achieves the performance requirements in paragraph (d)(11) of this section by conducting a performance test as specified in paragraphs (d)(2) through ( 10) of this section. Yo u must submit a test report for each combustionPage **75** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only control device in accordance with the requirements in paragraph (d)(12) of this section. (2) Performance testing must consist of three one

- hour (or longer) test runs for each of the four firing rate settings specified in paragraphs (d)(2)(i) through (iv) of this section , making a total of 12 test runs per test. Propene (propylene) gas must be used for the testing fuel. All fuel analyses must be performed by an independent third

- party laboratory (not affiliate d with the control device manufacturer or fuel supplier). (i) 90

- 100 percent of maximum design rate (fixed rate). (ii) 70

- 100

- 70 percent (ramp up, ramp down). Begin the test at 70 percent of the maximum design rate. During the first 5 minutes, inc rementally ramp the firing rate to 100 percent of the maximum design rate. Hold at 100 percent for 5 minutes. In the 10

- 15 minute time range, incrementally ramp back down to 70 percent of the maximum design rate. Repeat three more times for a total of 60 m inutes of sampling. (iii) 30

- 70

- 30 percent (ramp up, ramp down). Begin the test at 30 percent of the maximum design rate. During the first 5 minutes, incrementally ramp the firing rate to 70 percent of the maximum design rate. Hold at 70 percent for 5 minutes. In the 10

- 15 minute time range, incrementally ramp back down to 30Page **76** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only percent of the maximum design rate. Repeat three more times for a total of 60 minutes of sampling. (iv) 0

- 30

- 0 percent (ramp up, ramp down). Begin the test at the minimum f iring rate. During the first 5 minutes, incrementally ramp the firing rate to 30 percent of the maximum design rate. Hold at 30 percent for 5 minutes. In the 10

- 15 minute time range, incrementally ramp back down to the minimum firing rate. Repeat three mor e times for a total of 60 minutes of sampling. (3) All models employing multiple enclosures must be tested simultaneously and with all burners operational. Results must be reported for each enclosure individually and for the average of the emissions from all interconnected combustion enclosures/chambers. Control device operating data must be collected continuously throughout the performance test using an electronic Data Acquisition System. A graphic presentation or strip chart of the control device operat ing data and emissions test data must be included in the test report in accordance with paragraph (d)(12) of this section. Inlet fuel meter data may be manually recorded provided that all inlet fuel data readings are included in the final report. (4) Inl et testing must be conducted as specified in paragraphs (d)(4)(i) through (ii) of this section.Page **77** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i) The inlet gas flow metering system must be located in accordance with Method 2A , 40 CFR part 60, appendix A

- 1, (or other approved procedure) to measure inlet gas flow rate at the control device inlet location. You must position the fitting for filling fuel sample containers a minimum of eight pipe diameters upstream of any inlet gas flow monitoring meter. (ii) Inlet flow rate must be determined using M ethod 2A , 40 CFR part 60, appendix A

- 1. Record the start and stop reading for each 60

- minute THC test. Record the gas pressure and temperature at 5

- minute intervals throughout each 60

- minute
test. (5) Inlet gas sampling must be conducted as specified in paragraphs (d)(5)(i) through (ii) of this section. (i) At the inlet gas sampling location, securely connect a Silonite

- coated stainless steel evacuated canister fitted with a flow controller sufficient to fill the canister over a 3

- hour period. Filli ng must be conducted as specified in paragraphs (d)(5)(i)(A) through (C) of this section. (A) Open the canister sampling valve at the beginning of each test run, and close the canister at the end of each test

run. (B) Fill one canister across the three test runs such that one composite fuel sample exists for each test condition.Page **78** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (C) Label the canisters individually and record sample information on a chain of custody form. (ii) Analyze each inlet gas sample using the methods in paragraphs (d)(5)(ii)( A) through (C) of this section. You must include the results in the test report required by paragraph (d)(12) of this section. (A) Hydrocarbon compounds containing between one and five atoms of carbon plus benzene using ASTM D1945

- 03. (B) Hydrogen (H 2 ) , carbon monoxide (CO), carbon dioxide (CO 2 ), nitrogen (N 2 ), oxygen (O 2 ) using ASTM D1945

- 03. (C) Higher heating value using ASTM D3588

- 98 or ASTM D4891 89. (6) Outlet testing must be conducted in accordance with the criteria in paragraphs (d)(6)(i) th rough (v ) of this section. (i) Sample and flow rate must be measured in accordance with paragraphs (d)(6)(i)(A) through ( B) of this section. (A) The outlet sampling location must be a minimum of four equivalent stack diameters downstream from the hig hest peak flame or any other flow disturbance, and a minimum of one equivalent stack diameter upstream of the exit or any other flow disturbance. A minimum of two sample ports must be used. (B) Flow rate must be measured using Method 1 , 40 CFR part 60 , appendix A

- 1 for determining flow measurement traverse point location, and Method 2 , 40 CFR part 60, appendix A

- 1 forPage **79** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only measuring duct velocity. If low flow conditions are encountered ( i.e. , velocity pressure differentials less than 0.05 inches of
water ) during the performance test, a more sensitive manometer must be used to obtain an accurate flow profile. (ii) Molecular weight and excess air must be determined as specified in paragraph (d)(7) of this section. (iii) Carbon monoxide must be determine d as specified in paragraph (d)(8) of this section. (iv) THC must be determined as specified in paragraph (d)(9) of this section. (v) V isible emissions must be determined as specified in paragraph (d)(10) of this section. (7) Molecular weight and excess air determination must be performed as specified in paragraphs (d)(7)(i) through (iii) of this section. (i) An integrated bag sample must be collected during the Method 4 , 40 CFR part 60, a ppendix A

- 3, moisture test following the procedure specified in (d)(7)(i)(A) through (B) of this section

. Analyze the bag sample using a gas chromatograph

thermal conductivity detector (GC

- TCD) analysis meeting the criteria in paragraphs (d)(7)(i)(C) through (D) of this section. (A) Collect the integrated sample t hroughout the entire test, and collect representative volumes from each traverse location.Page **80** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (B) Purge the sampling line with stack gas before opening the valve and beginning to fill the bag. Clearly label each bag and record sample information on a chain of custody form. (C) The bag contents must be vigorously mixed prior to the gas chromatograph analysis. (D) The GC

- TCD calibration procedure in Method 3C , 40 CFR part 60, a ppendix A, must be modified by using EPA Alt

- 045 as follows: For the initial calibration, triplicate injections of any single concentration must agree within 5 percent of their mean to be valid. The calibration response factor for a single concentration re

- check must be within 10 percent of the original calibration response factor for that concentration. If this criterion is not met, repeat the initial calibration using at least three concentration levels. (ii) Calculate and report the molecular weight of oxygen, carbon dioxide, methane, and nitrogen in the integrated bag sample a nd include in the test report specified in paragraph (d)(12) of this section. Moisture must be determined using Method 4 , 40 CFR part 60, appendix A

- 3. Traverse both ports with the Method 4 , 40 CFR part 60, appendix A

- 3, sampling train during each te st run. Ambient air must not be introduced into the Method 3C , 40 CFR part 60, a ppendix A

- 2, integrated bag sample during the port change.Page **81** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iii) Excess air must be determined using resultant data from the EPA Method 3C tests and EPA Method 3B , 40 CF R part 60,

a ppendix A, equation 3B

- 1. (8) Carbon monoxide must be determined using Method 10 , 40 CFR part 60, a ppendix A. Run the test simultaneously with Method 25A , 40 CFR part 60, appendix A

- 7 using the same sampling points. An instrument range o f 0

- 10 parts per million by volume

dry (ppmvd) is recommended. (9) Total hydrocarbon determination must be performed as specified by in paragraphs (d)(9)(i) through (vii) of this section. (i) Conduct THC sampling using Method 25A , 40 CFR part 60,
app endix A

- 7, except that the option for locating the probe in the center 10 percent of the stack is not allowed. The THC probe must be traversed to 16.7 percent, 50 percent, and 83.3 percent of the stack diameter during each test run. (ii) A valid test mus t consist of three Method 25A , 40 CFR part 60, appendix A

- 7, tests, each no less than 60 minutes in duration. (iii) A 0

- 10 parts per million by volume

- wet (ppmvw) (as propane) measurement range is preferred; as an alternative a 0

- 30 ppmvw (as carbon) measurement range may be used. (iv) Calibration gases must be propane in air and be certified through EPA Protocol 1

– “EPA Traceability ProtocolPage **82** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only for Assay and Certification of Gaseous Calibration Standards,” September 1997, as amended August 25, 1999, E PA

– 600/R

– 97/121(or more recent if updated since 1999). (v) THC measurements must be reported in terms of ppmvw as
propane. (vi) THC results must be corrected to 3 percent CO 2 , as measured by Method 3C , 40 CFR part 60, appendix A

- 2. You must use the following equation for this d iluent concentration correction :

C corr = Cmeas � 3 CO 2meas �

Where:
C meas = T he measured concentration of the pollutant

. CO 2meas = T he measured concentration of the CO 2 diluent

. 3 = T he corrected reference concentration of CO 2 diluent

. C corr = T he corrected concentration of the pollutant. (vii) Subtraction of methane or ethane from the THC data is not allowed in determining results. (10) Visible emissions must be determined using Method 22 , 40 CFR part 60, a ppendix A. Th e test must be performed continuously during each test run. A digital color photograph of the exhaust point, taken from the position of the observer and annotated with date and time, must be taken once per test runPage **83** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only and the 12 photos included in the test re port specified in paragraph (d)(12) of this section

. (11) Performance test criteria

. (i) The control device model tested must meet the criteria in paragraphs (d)(11)( i ) (A) through (D) of this section. These criteria must be reported in the test report required by paragraph (d)(12) of this section. ( A ) Method 22 , 40 CFR part 60, a ppendix A, results under paragraph (d)( 10) of this section with no indication of visible emissions

. ( B ) Average Method 25A , 40 CFR part 60, a ppendix A, results under par agraph (d)(9) of this section equal to or less than 10.0 ppmvw THC as propane corrected to 3.0 percent CO 2 . (C) Average CO emissions determined under paragraph (d)(8) of this section equal to or less than 10 parts ppmvd, corrected to 3.0 percent CO 2 . (D) Excess combustion air determined under paragraph (d)(7) of this section equal to or greater than 150 percent

. (ii) The manufacturer must determine a maximum inle t gas flow rate which must not be exceeded for each control device model to achieve the criteria in paragraph (d)(11)(iii) of this section. The maximum inlet gas flow rate must be included in the test report required by paragraph (d)(12) of this section

. (iii) A control device meeting the criteria in paragraph (d)(11)(i)(A) through (D) of this section must demonstrate aPage **84** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only destruction efficiency of 95 percent for VOC regulated under this subpart. (12) The owner or operator of a combustion control device mode l tested under this section must submit the information listed in paragraphs (d)(12)(i) through (vi) in the test report required by this section. (i) A full schematic of the control device and dimensions of the device components. (ii) The maximum net h eating value of the device. (iii) The test fuel gas flow range (in both mass and volume). Include the maximum allowable inlet gas flow rate. (iv) The air/stream injection/assist ranges, if used. (v) The test conditions listed in paragraphs (d)(12)(v) (A) through (O) of this section, as applicable for the tested model. (A) Fuel gas delivery pressure and temperature. (B) Fuel gas moisture range. (C) Purge gas usage range. (D) Condensate (liquid fuel) separation range. (E) Combustion zone temper ature range. This is required for all devices that measure this parameter. (F) Excess combustion air range. (G) Flame arrestor(s). (H) Burner manifold. (I) Pilot flame indicator.Page **85** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (J) Pilot flame design fuel and calculated or measured fuel
usage. (K) Tip velocity range. (L) Momentum flux ratio. (M) Exit temperature range. (N) Exit flow rate. (O) Wind velocity and direction. (vi) The test report must include all calibration quality assurance/quality control data, calibration gas values, gas cylinder certification, strip charts, or other graphic presentations of the data annotated with test times and calibration values. (e) Continuous compliance for combustion control devices tested by the manufacturer in accordance with paragraph (d) of this section . This paragraph applies to the demonstration of compliance for a combustion control device tested under the provisions in paragraph (d) of this section. Owners or operators must demonstrate that a control device achieves the performance requi rements in (d)(11) of this section by installing a device tested under paragraph (d) of this section and complying with the criteria specified in par a graphs (e)(1) through (6) of this section. (1) The inlet gas flow rate must be equal to or less than the maximum specified by the manufacturer.Page **86** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) A pilot flame must be present at all times of operation. (3) Devices must be operated with no visible emissions, except for periods not to exceed a total of 2 minutes during any hour. A visible emissions test u sing Method 22 , 40 CFR part 60,

a ppendix A, must be performed each calendar quarter. The observation period must be 1 hour and must be conducted according to EPA Method 22 , 40 CFR part 60 , appendix A

. (4) Devices failing the visible emissions test must follow manufacturer’s repair instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All repairs and maintenance activities for each unit

m ust be recorded in a maintenance and repair log and must be available on site for inspection. ( 5 ) Following return to operation from maintenance or repair activity, each device must pass a n EPA Method 22 , 40 CFR part 60, Appendix A, visual observatio n as described in paragraph ( e )(3) of this section. ( 6 ) If the owner or operator operates a combustion control device model tested under this section, an electronic copy of the performance test results required by this section shall be submitted via email to Oil_and_Gas_PT@EPA.GOV unless the testPage **87** of **1 76** 

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only results for that model of combustion control device are posted at the following website: epa.gov/airquality/oilandgas /. (d) Performance testing for combustion control devices

- manufacturers’ performance test . T he manufacturer must demonstrate that a specific model of combustion control device achieves the performance requirements in paragraph (d)(1) of this section by conducting a performance test as specified in paragraphs (d)(2) through (8) of this section. Yo u must submit a test report for each combustion control device in accordance with the requirements in paragraphs (d)(9) of this section. (1) The manufacturer must meet the performance test criteria in paragraphs (d)(1)(i) through (iii) of this section. ( i) The control device model tested must meet the emission levels in paragraphs (d)(1)(i)(A) through (C) of this section. (A) Method 22 at 40 CFR part 60, appendix A

- 7, results under paragraph (d)(6)(iv) of this section with no indication of visible emissi ons. (B) Average Method 25A at 40 CFR part 60, appendix A

- 7, results under paragraph (d)(8) of this section equal to or less than 10.0 parts per million by volume

- wet THC as propane corrected to 3.0 percent carbon dioxide, and (C) Average carbon monoxid e emissions determined under paragraph (d)(6)(iii) of this section equal to or less than 10Page **88** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only parts per million by volume

- dry, corrected to 3.0 percent carbon dioxide. (ii) The manufacturer must determine a maximum inlet gas flow rate, which must not be exc eeded for each control device model to achieve the criteria in paragraph (d)(1)(i) of this section. (iii) A control device meeting the emission levels in paragraph (d)(1)(i)(A) through (C) of this section must demonstrate a minimum destruction efficiency of 95.0 percent for VOC regulated under this subpart. (2) Performance testing must consist of three one

- hour (or longer) test runs for each of the four firing rate settings in paragraphs (d)(2)(i) through (iv) of this section, making a total of 12 test ru ns per test. The manufacturer must use propene (propylene) gas for the testing fuel. An independent third

- party laboratory (not affiliated with the control device manufacturer or fuel supplier) must perform all fuel analyses. (i) 90

- 100 percent of maxim um design rate (fixed rate). (ii) 70

- 100

- 70 percent (ramp up, ramp down). Begin the test at 70 percent of the maximum design rate. Within the first 5 minutes, ramp up the firing rate to 100 percent of the maximum design rate. Hold at 100 percent for 5 minutes. In the 10

- 15 minute time range, ramp back down to 70 percent of the maximumPage **89** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only design rate. Repeat three more times for a total of 60 minutes of sampling. (iii) 30

- 70

- 30 percent (ramp up, ramp down). Begin the test at 30 percent of the maximum design rate. Within the first 5 minutes, ramp up the firing rate to 70 percent of the maximum design rate. Hold at 70 percent for 5 minutes. In the 10

- 15 minute time range, ramp back down to 30 percent of the maximum design rate. Repeat three more times fo r a total of 60 minutes of sampling. (iv) 0

- 30

- 0 percent (ramp up, ramp down). Begin the test at 0 percent of the maximum design rate. Within the first 5 minutes, ramp up the firing rate to 100 percent of the maximum design rate. Hold at 30 percent fo r 5 minutes. In the 10

- 15 minute time range, ramp back down to 0 percent of the maximum design rate. Repeat three more times for a total of 60 minutes of sampling. (3) The manufacturer must test all models employing multiple enclosures simultaneously and with all burners operational. The manufacturer must report results for each enclosure individually and for the average of the emissions from all interconnected combustion enclosures/chambers. Control device operating data must be collected continuously thr oughout the performance test using an electronic Data Acquisition SystemPage **90** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only and strip chart. The manufacturer must submit data with the test report in accordance with paragraph (d)(9) of this section. (4) The manufacturer must conduct inlet testing as specif ied in paragraphs (d)(4)(i) through (iii) of this section. (i) The fuel flow metering system must be located in accordance with Method 2A at 40 CFR part 60, appendix A

- 1, (or other approved procedure) to measure fuel flow rate at the control device inlet location. You must position the fitting for filling fuel sample containers a minimum of eight pipe diameters upstream of any inlet fuel flow monitoring meter. (ii) The manufacturer must determine the inlet flow rate using Method 2A at 40 CFR part 60, appe ndix A

- 1. Record the start and stop reading for each 60

- minute THC test. Record the gas pressure and temperature at 5

- minute intervals throughout each 60

- minute THC test. (iii) The manufacturer must conduct inlet fuel sampling in accordance with the crite ria in paragraph (d)(5) of this section. (5) The manufacturer must conduct inlet fuel sampling as specified in paragraphs (d)(5)(i) and (ii) of this section. (i) At the inlet fuel sampling location, the manufacturer must securely connect a Silonite

- coate d stainless steel evacuated canister fitted with a flow controller sufficient to fill the canister over a 1 hour period. Filling must bePage **91** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only conducted as specified in paragraphs (d)(5)(i)(A) through (C) of this section. (A) Open the canister sampling valve a t the beginning of the total hydrocarbon test, and close the canister at the end of the total hydrocarbon test. (B) Fill one canister for each total hydrocarbon test run. (C) Label the canisters individually and record on a chain of custody form. (ii) T he manufacturer must analyze each fuel sample using the methods in paragraphs (d)(5)(ii)(A) through (D) of this section. You must include the results in the test report in paragraph (d)(9) of this section. (A) Hydrocarbon compounds containing between one and five atoms of carbon plus benzene using ASTM D1945

- 03 (Reapproved 2010) (incorporated by reference as specified in §60.17)

. (B) Hydrogen (H 2 ), carbon monoxide (CO), carbon dioxide (CO 2 ), nitrogen (N 2 ), oxygen (O 2 ) using ASTM D1945

- 03 (Reapproved 2010) (incorporated by reference as specified in §60.17)

. (C) Carbonyl sulfide, carbon disulfide plus mercaptans using ASTM D5504

- 08 (incorporated by reference as specified in §60.17)
. (D) Higher heating value using ASTM D3588

- 98 (Reapproved 2003) or ASTM D48 91

- 89 (Reapproved 2006) (incorporated by reference as specified in §60.17)

.Page **92** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (6) The manufacturer must conduct outlet testing in accordance with the criteria in paragraphs (d)(6)(i) through (iv) and (d)(7) of this section. (i) The manufacturer must sample and measure flowrate in accordance with the following: (A) The manufacturer must position the outlet sampling location a minimum of four equivalent stack diameters downstream from the highest peak flame or any other flow disturbance, and a minimum of one equivalent stack diameter upstream of the exit or any other flow disturbance. A minimum of two sample ports must be used. (B) The manufacturer must measure flow rate using Method 1 at 40 CFR part 60, appendix A

- 1 for determining flow measurement
travers e point location, and Method 2 at 40 CFR part 60, appendix A

- 1 for measuring duct velocity. If low flow conditions are encountered ( i.e. , velocity pressure differentials less than 0.05 inches of water) during the performance test, a more sensitive manomete r must be used to obtain an accurate flow profile. (ii) The manufacturer must determine molecular weight as specified in paragraph (d)(7) of this section. (iii) The manufacturer must determine carbon monoxide using Method 10 at 40 CFR part 60, appendix A

- 4 or ASTM D6522

- 00 (Reapproved 2005) (incorporated by reference as specified inPage **93** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only §60.17) . The manufacturer must run the test at the same time and with the sample points used for the Method 25A at 40 CFR part 60, appendix A

- 7, testing. An instrument range of 0

- 10 parts per million by volume

- dry (ppmvd) must be used. (iv) The manufacturer must determine visible emissions using Method 22 at 40 CFR part 60, appendix A

- 7. The test must be performed continuously during each test run. A digital color photograph of the exhaust point, taken from the position of the observer and annotated with date and time, will be taken once per test run and the four photos included in the test report. (7) The manufacturer must determine molecular weight as specified in paragrap hs (d)(7)(i) and (ii) of this section. (i) The manufacturer must collect an integrated bag sample during the Method 4 at 40 CFR part 60, appendix A

- 3, moisture test. The manufacturer must analyze the bag sample using a gas chromatograph

- thermal conductivi ty detector (GC

- TCD) analysis meeting the criteria in paragraphs (d)(7)(i)(A) through (D) of this section. (A) Collect the integrated sample throughout the entire test, and collect representative volumes from each traverse location. (B) Purge the samplin g line with stack gas before opening the valve and beginning to fill the bag.Page **94** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (C) Knead or otherwise vigorously mix the bag contents prior to the gas chromatograph analysis. (D) Modify the gas chromatograph

- thermal conductivity detector calibration proce dure in Method 3C at 40 CFR part 60, appendix A

- 2 by using EPA Alt

- 045 as follows: For the initial calibration, triplicate injections of any single concentration must agree within 5 percent of their mean to be valid. The calibration response factor for a s ingle concentration re

- check must be within 10 percent of the original calibration response factor for that concentration. If this criterion is not met, repeat the initial calibration using at least three concentration levels. (ii) The manufacturer must r eport the molecular weight of oxygen, carbon dioxide, methane, and nitrogen and include in the test report submitted under § 60.5420(b)(7) . The manufacturer must determine moisture using Method 4 at 40 CFR part 60, appendix A

- 3. Traverse both ports with the Method 4 at 40 CFR part 60, appendix A

- 3, sampling train during each test run. The manufacturer must not introduce ambient air into the Method 3C at 40 CFR part 60, appendix A

- 2, integrated bag sample during the port change. (8) The manufacturer must det ermine total hydrocarbons as specified by the criteria in paragraphs (d)(8)(i) through (vii) of this section.Page **95** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i) Conduct THC sampling using Method 25A at 40 CFR part 60, appendix A

- 7, except the option for locating the probe in the center 10 percent of t he stack is not allowed. The THC probe must be traversed to 16.7 percent, 50 percent, and 83.3 percent of the stack diameter during the testing. (ii) A valid test must consist of three Method 25A at 40 CFR part 60, appendix A

- 7, tests, each no less than 6 0 minutes in duration. (iii) A 0

- 10 parts per million by volume

- wet (ppmvw) (as propane) measurement range is preferred; as an alternative a 0

- 30 ppmvw (as carbon) measurement range may be used. (iv) Calibration gases will be propane in air and be certif ied through EPA Protocol 1

– “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards,” September 1997, as amended August 25, 1999, EPA

– 600/R

– 97/121. (v) THC measurements must be reported in terms of ppmvw as
propane. (vi) THC results must be corrected to 3 percent CO 2 , as measured by Method 3C at 40 CFR part 60, appendix A

- 2. (vii) Subtraction of methane/ethane from the THC data is not allowed in determining results. (9) For each combustion control device model tested by the manufacturer under this section, you must maintain records ofPage **96** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the information listed in paragraphs (d)(9)(i) through (vi) of this section. (i) A full schematic of the control device and dimensions of the device components. (ii) The design net heating value (minimum and maximum) of the device. (iii) The test fuel gas flow range (in both mass and volume). Include the minimum and maximum allowable inlet gas flow rate. (iv) The air/stream injection/assist ranges, if used. (v) The test parameter ranges listed in paragraphs (d)(9)(v)(A) through (O) of this section, as applicable for the tested model. (A) Fuel gas delivery pressure and temperature. (B) Fuel gas moisture range. (C) Purge gas usage range. (D) Condensate (liquid fuel) separation range. (E) Combustion zone temperature range. This is required for all devices that measure this parameter. (F) Excess combustion air range. (G) Flame arrestor(s). (H) Burner manifold pressure. (I) Pilot flame sensor. (J) Pilot flame design fuel and fuel usa ge.Page **97** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (K) Tip velocity range. (L) Momentum flux ratio. (M) Exit temperature range. (N) Exit flow rate. (O) Wind velocity and direction. (vi) You must include all calibration quality assurance/quality control data, calibration gas values, gas cylinder c ertification, and strip charts annotated with test times and calibration values in the test report. **§60.5415 How do I demonstrate continuous compliance with the standards for my gas**  **well affected facility, my centrifugal**  **compressor affected facility, my st ationary reciprocating**  **compressor affected facility, my pneumatic controller affected facility, my storage vessel affected facility, and my affected**  **facilities at onshore natural gas processing plants?** (a) For each gas well affected facility, you must dem onstrate continuous compliance by submitting the reports required by §60.5420(b) and maintaining the records for each completion operation specified in §60.5420 (c)(1)
. (b) For each centrifugal compressor affected facility, you must demonstrate continuous compliance according to paragraph s (b)(1) and through ( 2 3 ) of this section.Page **98** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (1) You must reduce VOC emissions from the wet seal fluid degassing system by 95 .0 percent or greater. (2) If you use a For each control device used to reduce emissions, you m ust demonstrate continuous compliance according
to paragraph (e)(2) of this section

. with the performance requirements of §60.5412(a) using the procedure s specified in paragraphs ( b )( 2 ) (i) through (vii) of this section. If you use a condenser as the control device to achieve the requirements specified in §60.5412(a)(2), you must demonstrate compliance according to paragraph ( b )( 2 ) (viii) of this section. You may switch between compliance with paragraphs ( b )( 2 ) (i) through (vii) of this section and compliance w ith paragraph ( b )( 2 ) (viii) of this section only after at least 1 year of operation in compliance with the selected approach. You must provide notification of such a change in the compliance method in the
next Annual Report, as required in § 60.5420(b) , foll owing the change. ( i ) You must operate below (or above) the site specific maximum (or minimum) parameter value establish ed according to the requirements of §60.5417(f)(1). ( ii ) You must calculate the daily average of the applicable monitored parameter in accordance with §60.5417(e) except that the inlet gas flow rate to the control device must not be averaged.Page **99** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( iii ) Compliance with the operating parameter limit is achieved when the daily average of the monitoring parameter value calculated under paragrap h ( b )(2) (ii) of this section is either equal to or greater than the minimum monitoring value or equal to or less than the maximum monitoring value established under paragraph ( b )( 2 ) (i) of this section. When performance testing of a combustion control dev ice is conducted by the device manufacturer as specified in §60.5413(d), compliance with the operating parameter limit is achieved when the criteria in §60.5413(e) are met
. ( iv ) You must operate the continuous monitoring system required in §60.5417 at all times the affected source is operating, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments). A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in par t by poor maintenance or careless operation are not malfunctions. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.Page **100** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( v ) Yo u may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. Y ou must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system. ( vi ) Failure to collect required data is a deviation of the monitoring requirements, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required quality monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zer o and span adjustments). ( vii ) If you use a combustion control device to meet the requirements of §60.5412(a) and you demonstrate compliance using the test procedures specified in §60.5413(b ), you must comply with paragraphs (b)(2)(vii)(A) through (D) o f this section. ( A ) A pilot flame must be present at all times of operation. ( B ) Devices must be operated with no visible emissions, except for periods not to exceed a total of 2 minutes during any hour. A visible emissions test using Method 22 , 40 CFR p art 60,

a ppendix A, must be performed each calendar quarter. ThePage **101** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only observation period must be 1 hour and must be conducted according to EPA Method 22 , 40 CFR part 60 , appendix A

. ( C ) Devices failing the visible emissions test must follow manufacturer’s rep air instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All repairs and maintenance activities for each unit must be recorded in a maintenan ce and repair log and must be available on site for inspection. ( D ) Following return to operation from maintenance or repair activity, each device must pass a Method 22 , 40 CFR part 60, Appendix A, visual observation as described in paragraph (b)(2) (vi i )( B ) of this section. ( viii ) If you use a condenser as the control device to achieve the percent reduction performance requirements specified in §60.5412(a)(2), you must demonstrate compliance using the
proce dures in paragraphs ( b )(2)(viii)(A) through (E) of this section. ( A ) You must establish a site

- specific condenser performance curve according to §60.5417(f)(2). ( B ) You must calculate the daily average condenser outlet temperature in accordance with §6 0.5417(e). ( C ) You must determine the condenser efficiency for the current operating day using the daily average condenser outletPage **102** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only temperature calculated under paragraph ( b )(2)(viii)(B) of this section and the condenser performance curve established under paragraph ( b )(2)(viii)(A) of this section. ( D ) Except as provided in paragraphs ( b )(2)(viii)(D)( 1 ) and ( 2 ) of this section, at the end of each operating day, you must calculate the 365

- day rolling average TOC emission reduction, as appropriate, from th e condenser efficiencies as determined in paragraph ( b )(2)(viii)(C) of this section. ( 1 ) After the compliance dates specified in § 60.5370 , if you have less than 120 days of data for determining average TOC emission reduction, you must calculate the aver age TOC emission reduction for the first 120 days of operation after the compliance dates. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the 120

- day average TOC emission reduction is equal to or greater than 9 5 .0
p ercent. ( 2 ) After 120 days and no more than 364 days of operation after the compliance date specified in § 60.5370 , you must calculate the average TOC emission reduction as the TOC emission reduction averaged over the number of days between the current da y and the applicable compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement, if the average TOC emission reduction is equal to or greater than 9 5 .0 percent.Page **103** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( E ) If you have data for 365 days or more of oper ation, you have demonstrated compliance with the TOC emission reduction if the rolling 365

- day average TOC emission reduction calculated in paragraph ( b )(2)(viii)(D) of this section is equal to or greater than 95.0 percent.

(3) You must submit the annua l report required by 60.5420(b) and maintain the records as specified in §60.5420(c)(2). (c) For each reciprocating compressor affected facility,
you must demonstrate continuous compliance according to paragraphs (c)(1) through ( 3 ) of this section

. (1) Y ou must continuously monitor the number of hours of operation for each reciprocating compressor affected facility or track the number of months since initial startup, or October 15, 2012, or the date of the most recent reciprocating compressor rod packing replacement, whichever is later. (2) You must submit the annual report as required in §60.5420(b) and maintain records as required in §60.5420(c)(3)

. ( 3 ) You must replace the reciprocating compressor rod packing before the total number of hours of opera tion reaches 26,000 hours or the number of months since the most recent rod packing replacement reaches 36 months

.Page **104** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (d) For each pneumatic controller affected facility, you must demonstrate continuous compliance according to paragraphs (d)(1) through (3) o f this section. (1) You must continuously operate the pneumatic controllers as required in §60.5390(a), (b) , or (c). (2) You must submit the annual report as required in §60.5420(b). (3) You must maintain records as required in §60.5420(c)(4). (e) For each storage vessel affected facility for which the VOC emissions are greater than 6 tpy , you must demonstrate continuous compliance according to paragraphs (e)( 1 ) and ( 2 ) of this section. Y ou must demonstrate continuous compliance according to paragraph ( e)( 3 ) of this section for each storage vessel affected facility, for which you are using a control device or routing emissions to a flow line to meet the requirement of §60.5395( d ) (1)
. (1) [Reserved] You must reduce VOC emissions fro m each storage vessel are reduced by 95.0 percent or greater. (2) [Reserved] If you use a control device to reduce VOC emissions, you must demonstrate continuous compliance with the performance requirements of §60.5412(a)(2) using the procedure s specified in paragraphs ( e )( 2 ) (i) through (vii) of this section. If you use a condenser as the control device to achieve thePage **105** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only requirements specified in §60.5412(a)(2), you may demonstrate compliance according to paragraph ( e )( 2 ) (viii) of this section. You may switch between compliance with paragraphs ( e )( 2 ) (i) through (vii) of this section and compliance with paragraph (e)( 2 ) (viii) of this section only after at least 1 year of operation in compliance with the selected approach. You must provide notification of such a change in the compliance method in the next Annual Report, as required in § 60.5420(b) , following the change. ( i ) You must operate below (or above) the site specific maximum (or minimum) parameter value establish ed according to the requirements of §60.541 7(f)(1). ( ii ) You must calculate the daily average of the applicable monitored parameter in accordance with §60.5417(e) except that the inlet gas flow rate to the control device must not be averaged. ( iii ) Compliance with the operating parameter limit is achieved when the daily average of the monitoring parameter value calculated under paragraph (e)(2) (ii) of this section is either equal to or greater than the minimum monitoring value or equal to or less than the maximum monitoring value established under paragraph (e)( 2 ) (i) of this section. When performance testing of a combustion control device is conducted by the device manufacturer as specified in §60.5413(d), compliance withPage **106** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the operating parameter limit is achieved when the inlet gas flow rate is equ al to or less than the value established under §60.5413(d)(1)(ii)

. ( iv ) You must operate the continuous monitoring system required in §60.5417 at all times the affected source is operating, except for periods of monitoring s ystem malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments). A monitori ng system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. You are

r equired to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable. ( v ) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. You must use all the data collected during all other required data collectio n periods to assess the operation of the control device and associated control system.Page **107** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( vi ) Failure to collect required data is a deviation of the monitoring requirements, except for periods of monitoring system malfunctions, repairs associated with moni toring system malfunctions, and required quality monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments). ( vii ) If you use a combustion control device to m eet the requirements of §60.5412(a) , you must demonstrate compliance by installing a device tested under the provisions i n §60.5413 (b)

or (d) and complying with the criteria in paragraphs (e)(2)(vii)(A) through (D) of this section. ( A ) The inlet gas flow rate must meet the range specified by the manufacturer. You must measure the flow rate as specified in §60.5417(d)(1)(viii)(A). ( B ) A pilot flame must be present at all times of operation. You must monitor the pilot flame in accordance with §60.5417(d)(1)(viii)(B). ( C ) You must operate the combustion control device with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. You must perform a visible emissions test using Method 22 at 40 CFR part 60, appendix A

- 7 monthly. The observation period must be 2 hours and must follow Method 22.Page **108** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( D ) Compliance with the operating parameter limit is achieved when the criteria in paragraphs (e)(2)(vii)(D)( 1 ) through ( 5 ) are met. ( 1 ) The inlet gas flow rate monitored under paragraph (e)(2)(vii)(A) of this section is equal to or below the maximum established by the manufacturer. ( 2 ) The pilot flame is present at all times; and ( 3 ) During the visible emissions test performed under paragraph (e)(2)(vii)(C) of this section, the duration of visible emissions does not exceed a total of 5 minutes during the observation period. Devices failing the v isible emissions test must follow the requirements in paragraphs (e)(2)(vii)(D)( 4 ) and ( 5 ) of this section

. ( 4 ) Following the first failure, you must replace the fuel nozzle(s) and burner tubes. ( 5 ) If, following rep lacement of the fuel nozzle(s) and burner tubes as specified in paragraph (e)(2)(vii)(D)( 4 ) of this section, the visible emissions test is not passed in the next scheduled test, you must either conduct a performance test as specified in §60.5413, or replac e the device with another control device whose model was tested and meets the requirements in §60.5413(d). ( viii ) If you use a condenser as the control device to achieve the percent reduction performance requirements specifiedPage **109** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only in §60.5412(a)(2), you must demonstrate compliance using the procedures in paragraphs (e)(2)(viii)(A) through (E) of this section. ( A ) You must establish a site

- specific condenser performance curve according to §60.5417(f)(2). ( B ) You must calculate the daily average condenser out let temperature in accordance with §60.5417(e). ( C ) You must determine the condenser efficiency for the current operating day using the daily average condenser outlet temperature calculated under paragraph (e)(2)(viii)(B) of this section and the condenser performance curve established under paragraph (e)(2)(viii)(A) of this section. ( D ) Except as provided in paragraphs (e)(2)(viii)(D)( 1 ) and ( 2 ) of this section, at the end of each operating day, you must calculate the 365

- day rolling average TOC emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (e)(2)(viii)(C) of this section. ( 1 ) After the compliance dates specified in § 60.5370 , if you have less than 120 days of data for determining average TOC emission reduc tion, you must calculate the average TOC emission reduction for the first 120 days of operation after the compliance dates. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the 120

- dayPage **110** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only average TOC emission reduction i s equal to or greater than 9 5 .0 percent. ( 2 ) After 120 days and no more than 364 days of operation after the compliance date specified in § 60.5370 , you must calculate the average TOC emission reduction as the TOC emission reduction averaged over the numb er of days between the current day and the applicable compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement, if the average TOC emission reduction is equal to or greater than 9 5 .0 percent. ( E ) If you have data for 365 days or more of operation, you have demonstrated compliance with the TOC emission reduction if the rolling 365

- day average TOC emission reduction calculated in paragraph (e)(2)(viii)(D) of this section is equal to or greater than 95.0 percent. (3) For each storage vessel affected facility subject to §60.5395(d)(1) , you must comply with paragraphs (e)(3)(i) and (ii) of this section. (i) You must reduce VOC emissions by 95.0 percent or greater. ( ii ) Y ou must demonstrate continuous co mpliance with the performance requirements of §60.5412( d ) for each storage vessel affected facility using the procedure specified in paragraphPage **111** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (e)( 3 ) ( ii ) (A) and either (e) ( 3 ) (ii) (B) or (e) ( 3 ) (ii) (C) of this section. ( A ) You must comply with §60.5416(c) fo r each cover and closed vent system. ( B ) You must comply with §60.5417(h) for each control device. ( C ) Each closed vent system that routes emissions to a flow line , as defined in §60.5430, must be operational 95 percent of the year or greater.

(f) For affected facilities at onshore natural gas processing plants, continuous compliance with VOC requirements is demonstrated if you are in compliance with the requirements of §60.5400. (g) For each sweetening unit affected facility at onshore natural gas pro cessing plants, you must demonstrate continuous compliance with the standards for SO 2 specified in §60.5405(b) according to paragraphs (g)(1) and (2) of this section. (1) The minimum required SO 2 emission reduction efficiency (Z c ) is compared to the emiss ion reduction efficiency (R) achieved by the sulfur recovery technology. (i) If R ≥ Z c , your affected facility is in compliance. (ii) If R < Z c , your affected facility is not in compliance.Page **112** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) The emission reduction efficiency (R) achieved by the sulfur reduction technology must be determined using the procedures in §60.540 6(c)(1). (h) Affirmative defense for violations of emission standards during malfunction . In response to an action to enforce the standards set forth in §§60.5375, 60.5380, 60.5385, 60.5390, 60.5395, 60.5400, and 60.5405, you may assert an affirmative def ense to a claim for civil penalties for violations of such standards that are caused by malfunction, as defined at §60.2. Appropriate penalties may be assessed, however, if you fail to meet your burden of proving all of the requirements in the affirmative defense. The affirmative defense shall not be available for claims for injunctive relief. (1) To establish the affirmative defense in any action to enforce such a standard , you must timely meet the reporting requirements in § 60.5420(a) 60.5415(h)(2) , and m ust prove by a preponderance of evidence that: (i) The violation : (A) Was caused by a sudden, infrequent, and unavoidable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner ; and (B) Could not have been prevented through careful planning, proper design or better operation and maintenance practices; andPage **113** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (C) Did not stem from any activity or event that could have been foreseen and avoided, or planned for; and (D) Was not part of a recurring pattern indicative of inadequate design, operation, or maintenance; and (ii) Repairs were made as expeditiously as possible when a violation occurred . Off

- shift and overtime labor were used, to the extent practicable to make these repairs; and (iii) The frequency, amount and duration of the violation (including any bypass) were minimized to the maximum extent practicable; and (iv) If the violation resulted from a bypass of control equipment or a process, then the bypass was unavoidable to prevent loss o f life, personal injury, or severe property damage; and (v) All possible steps were taken to minimize the impact of the violation on ambient air quality, the environment and human health; and (vi) All emissions monitoring and control systems were kept in operation if at all possible, consistent with safety and good air pollution control practices; and (vii) All of the actions in response to the violation were documented by properly signed, contemporaneous operating logs; andPage **114** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (viii) At all times, the aff ected source was operated in a manner consistent with good practices for minimizing emissions; and (ix) A written root cause analysis has been prepared, the purpose of which is to determine, correct, and eliminate the primary causes of the malfunction and the violation resulting from the malfunction event at issue. The analysis shall also specify, using best monitoring methods and engineering judgment, the amount of any emissions that were the result of the malfunction. (2) Report . The owner or operator seeking to assert an affirmative defense shall submit a written report to the Administrator with all necessary supporting documentation , that it has met the requirements set forth in paragraph (h)(1) of this section. This affirmative defense report shall b e included in the first periodic compliance, deviation report or excess emission report otherwise required after the initial occurrence of the violation of the relevant standard (which may be the end of any applicable averaging period). If such compliance, deviation report or excess emission report is due less than 45 days after the initial occurrence of the violation, the affirmative defense report may be included in the second compliance, deviation report or excess emission report due afterPage **115** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the initial oc currence of the violation of the relevant standard. **§60.5416 What are the initial and continuous cover and closed vent system inspection and monitoring requirements for my**  **storage vessel and centrifugal compressor**  **affected facility?** For each closed vent s ystem or cover at your storage vessel or centrifugal compressor affected facility, you must comply with the applicable requirements of paragraphs (a) through (g) (c) of this section. (a) Inspections for closed vent system s and covers install ed on each centrifugal compressor affected facility

. Except as provided in paragraphs (e) and (f ) (b)(11) and (12) of this section, you must inspect each closed vent system according to the procedures and schedule specified in paragraphs (a)(1) and (2) of this section, inspect each cover according to the procedures and schedule specified in paragraph (a)(3) of this section, and inspect each bypass device according to the procedures of paragraph (a)(4) of this section. (1) For each closed vent system joi nt, seam, or other connection that is permanently or semi

- permanently sealed ( e.g. , a welded joint between two sections of hard piping or a bolted and gasketed ducting flange), you must meet the requirements specified in paragraphs (a)(1)(i) and (ii) of th is section.Page **116** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i) Conduct an initial inspection according to the test methods and procedures specified in paragraph (b) of this section to demonstrate that the closed vent system operates with no detectable emissions. You must maintain records of the inspec tion results as specified in §60.5420(c)(6)

. (ii) Conduct annual visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in piping; loose connections; liquid leaks; or brok en or missing caps or other closure devices. You must monitor a component or connection using the test methods and procedures in paragraph (b) of this section to demonstrate that it operates with no detectable emissions following any time the component is repaired or replaced or the connection is unsealed. You must maintain records of the inspection results as specified in §60.5420(c)(6)
. (2) For closed vent system components other than those specified in paragraph (a)(1) of this section, you must meet the requirements of paragraphs (a)(2)(i) through (iii) of this section. (i) Conduct an initial inspection according to the test methods and procedures specified in paragraph (b) of this section to demonstrate that the closed vent system operates withPage **117** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only no dete ctable emissions. You must maintain records of the inspection results as specified in §60.5420(c)(6)

. (ii) Conduct annual inspections according to the test methods and procedures specified in paragraph (b) of this section to demonstrate that the component s or connections operate with no detectable emissions. You must maintain records of the inspection results as specified in §60.5420(c)(6)

. (iii) Conduct annual visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in ductwork; loose connections; liquid leaks; or broken or missing caps or other closure devices. You must maintain records of the inspection results as specified in §60.5420(c)(6)

. (3) For each cover, you must meet the requirements in paragraphs (a)(3)(i) and (ii) of this section. (i) Conduct visual inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in the cover, or between the

cove r and the separator wall; broken, cracked, or otherwise damaged seals or gaskets on closure devices; and broken or missing hatches, access covers, caps, or other closure devices. In the case where the storage vessel is buried partially or entirely undergro und, you must inspect only those portions of the cover that extend to or above the ground surface, and thosePage **118** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only connections that are on such portions of the cover ( e.g. , fill ports, access hatches, gauge wells, etc.) and can be opened to the atmosphere. (ii) You must initially conduct the inspections specified in paragraph (a)(3)(i) of this section following the installation of the cover. Thereafter, you must perform the inspection at least once every calendar year, except as provided in paragraphs ( e b ) (11) a nd ( f ) (12) of this section. You must maintain records of the inspection results as specified in §60.5420(c)(7)
. (4) For each bypass device, except as provided for in §6 0 .5411, you must meet the requirements of paragraphs (a)(4)(i) or (ii) of this section

. (i) Set the flow indicator to take a reading at least once every 15 minutes at the inlet to the bypass device that could divert the steam away from the control device to the atmosphere. (ii) If the bypass device valve installed at the inlet to the bypa ss device is secured in the non

- diverting position using

a car - seal or a lock

- and

- key type configuration, visually inspect the seal or closure mechanism at least once every month to verify that the valve is maintained in the non

- diverting position and the vent stream is not diverted through the bypass device. You must maintain records of the inspections according
to § 60.5420(c)(8).Page **119** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (b) No detectable emissions test methods and procedures . If you are required to conduct an inspection of a closed vent system or cover at your storage vessel or centrifugal compressor affected facility as specified in paragraphs (a)(1), (2), or (3) of this section, you must meet the requirements of paragraphs (b)(1) through ( 13 ) of this section. (1) You must conduct the no det ectable emissions test procedure in accordance with Method 21 at 40 CFR part 60, appendix A

- 7. (2) The detection instrument must meet the performance criteria of Method 21 at 40 CFR part 60, appendix A

- 7, except that the instrument response factor criteri a in section 3.1.2(a) of Method 21 must be for the average composition of the fluid and not for each individual organic compound in the stream. (3) You must calibrate the detection instrument before use on each day of its use by the procedures specified i n Method 21 at 40 CFR part 60, appendix A

- 7. (4) Calibration gases must be as specified in paragraphs (b)(4)(i) and (ii) of this section. (i) Zero air (less than 10 parts per million by volume hydrocarbon in air). (ii) A mixture of methane in air at a c oncentration less than 10,000 parts per million by volume.Page **120** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (5) You may choose to adjust or not adjust the detection instrument readings to account for the background organic concentration level. If you choose to adjust the instrument readings for the back ground level, you must determine the background level value according to the procedures in Method 21 at 40 CFR part 60, appendix A

- 7. (6) Your detection instrument must meet the performance criteria specified in paragraphs (b)(6)(i) and (ii) of this secti on. (i) Except as provided in paragraph (b)(6)(ii) of this section, the detection instrument must meet the performance criteria of Method 21 at 40 CFR part 60, appendix A

- 7, except the instrument response factor criteria in section 3.1.2(a) of Method 21 m ust be for the average composition of the process fluid, not each individual volatile organic compound in the stream. For process streams that contain nitrogen, air, or other inerts that are not organic hazardous air pollutants or volatile organic compound s, you must calculate the average stream response factor on an inert

- free basis. (ii) If no instrument is available that will meet the performance criteria specified in paragraph (b)(6)(i) of this section, you may adjust the instrument readings by multipl ying by the average response factor of the process fluid, calculatedPage **121** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only on an inert

- free basis, as described in paragraph (b)(6)(i) of this section. (7) You must determine if a potential leak interface operates with no detectable emissions using the applicab le procedure specified in paragraph (b)(7)(i) or (ii) of this section. (i) If you choose not to adjust the detection instrument readings for the background organic concentration level, then you must directly compare the maximum organic concentration value measured by the detection instrument to the applicable value for the potential leak interface as specified in paragraph (b)(8) of this section. (ii) If you choose to adjust the detection instrument readings for the background organic concentration level, you must compare the value of the arithmetic difference between the maximum organic concentration value measured by the instrument and the background organic concentration value as determined in paragraph (b)(5) of this section with the applicable value f or the potential leak interface as specified in paragraph (b)(8) of this section. (8) A potential leak interface is determined to operate with no detectable organic emissions if the organic concentration value determined in paragraph (b)(7) of this sectio n is less than 500 parts per million by volume.Page **122** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( 9 ) Repairs . In the event that a leak or defect is detected, you must repair the leak or defect as soon as practicable according to the requirements of paragraphs (b)(9)( i ) and ( ii ) of this section, except a s provided in paragraph ( d b ) (10) of this section. ( i ) A first attempt at repair must be made no later than 5 calendar days after the leak is detected. ( ii ) Repair must be completed no later than 15 calendar days after the leak is detected. ( 10 ) Delay of repair . Delay of repair of a closed vent system or cover for which leaks or defects have been detected is allowed if the repair is technically infeasible without a shutdown, or if you determine that emissions resulting from immediate repair would be great er than the fugitive emissions likely to result from delay of repair. You must complete repair of such equipment by the end of the next shutdown. ( 11 ) Unsafe to inspect requirements . You may designate any parts of the closed vent system or cover as unsafe to inspect if the requirements in paragraphs (e)(1) (b)(11)(i) and (2 ) (ii) of this section are met. Unsafe to inspect parts are exempt from the inspection requirements of paragraphs (a)(1) through (3) of this section. ( A i ) You determine that the eq uipment is unsafe to inspect because inspecting personnel would be exposed to an imminent orPage **123** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only potential danger as a consequence of complying with paragraphs (a)(1), (2), or (3) of this section. ( B ii ) You have a written plan that requires inspection of the equipment as frequently as practicable during safe

- to

inspect times. ( 12 ) Difficult to inspect requirements . You may designate any parts of the closed vent system or cover as difficult to inspect, if the requirements in paragraphs (b)(12)( i ) and ( ii ) of t his section are met. Difficult to inspect parts are exempt from the inspection requirements of paragraphs (a)(1) through (3) of this section. ( i ) You determine that the equipment cannot be inspected without elevating the inspecting personnel more than 2 m eters above a support surface. ( ii ) You have a written plan that requires inspection of the equipment at least once every 5 years. ( 13 ) Records . Records shall be maintained as specified in this section and in § 60.5420(c)(9)
. ( c ) Cover and c losed v ent s y stem i nspections for storage vessel affected facilities

. If you install a control device or route emissions to a flow line, you must inspect each closed vent system according to the procedures and schedule specified in paragraphs ( c )(1) of t his section, inspect each cover according to the procedures and schedule specified in paragraphPage **124** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( c )( 2 ) of this section, and inspect each bypass device according to the procedures of paragraph ( c )( 3 ) of this section. You must also comply with the requiremen ts of (c)(4) through ( 8) of this section. (1) For each closed vent system, you must conduct an inspection at least once every calendar month as specified in paragraphs ( c )(1)(i) through ( i ii) of this section. (i) You must maintain records of the inspecti on results as specified in §60.5420(c)(6)

. (ii) Conduct olfactory, visual and auditory inspections for defects that could result in air emissions. Defects include, but are not limited to, visible cracks, holes, or gaps in piping; loose connections; liquid leaks; or broken or missing caps or other closure devices. (iii) Monthly inspections must be separated by at least 14 calendar days. ( 2 ) For each cover, you must conduct inspections at least once every calendar month as specified in paragraphs ( c )( 2 )( i) through ( i ii) of this section. (i) You must maintain records of the inspection results as specified in §60.5420(c)(7)

. (ii) Conduct olfactory, visual and auditory inspections for defects that could result in air emissions. Defects include, but
are not limited to, visible cracks, holes, or gaps in the cover,Page **125** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only or between the cover and the separator wall; broken, cracked, or otherwise damaged seals or gaskets on closure devices; and broken or missing hatches, access covers, caps, or other closure devices. I n the case where the storage vessel is buried partially or entirely underground, you must inspect only those portions of the cover that extend to or above the ground surface, and those connections that are on such portions of the cover ( e.g. , fill ports, a ccess hatches, gauge wells, etc.) and can be opened to the atmosphere. (iii) Monthly inspections must be separated by at least 14 calendar days. ( 3 ) For each bypass device, except as provided for in §6 0 .5411, you must meet the requirements of paragraphs ( c )( 3 )(i) or (ii) of this section. (i) Set the flow indicator to sound an alarm at the inlet to the bypass device when the stream is being divert ed away from the control device to the atmosphere. (ii) If the bypass device valve installed at the inlet to the bypass device is secured in the non

- diverting position using

a car - seal or a lock

- and

- key type configuration, visually inspect the seal or closure mechanism at least once every month to verify that the valve is maintained in the non

- diverting position and the vent stream is not diverted through the bypassPage **126** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only device. You must maintain records of the inspections according
to § 60.5420(c)(8). ( 4 ) Repairs . In the event that a leak or defect is detected, you must repai r the leak or defect as soon as practicabl e according to the requiremen ts of paragraphs (c)(4)(i) through (iii) of this section, except as provided in paragraph ( c ) (5) of this section. ( i ) A first attempt at repair must be made no later than 5 calendar days after the leak is detected. ( ii ) Repai r must be completed no later than 30 calendar days after the leak is detected. (iii) Grease or another applicable substance must be applied to deteriorating or cracked gaskets to improve the seal while awaiting repair. ( 5 ) Delay of repair . Delay of repai r of a closed vent system or cover for which leaks or defects have been detected is allowed if the repair is technically infeasible without a shutdown, or if you determine that emissions resulting from immediate repair would be greater than the fugitive em issions likely to result from delay of repair. You must complete repair of such equipment by the end of the next shutdown. ( 6 ) Unsafe to inspect requirements . You may designate any parts of the closed vent system or cover as unsafe to inspect if the requi rements in paragraphs (c)(6)(i) and (ii) of thisPage **127** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only section are met. Unsafe to inspect parts are exempt from the inspection requirements of paragraphs ( c )(1) and ( 2 ) of this section. ( i ) You determine that the equipment is unsafe to inspect because inspectin g personnel would be exposed to an imminent or potential danger as a consequence of complying with paragraphs ( c )(1) or (2) of this section. ( ii ) You have a written plan that requires inspection of the equipment as frequently as practicable during safe

- to

inspect times. ( 7 ) Difficult to inspect requirements . You may designate any parts of the closed vent system or cover as difficult to inspect, if the requirements in paragraphs (c)(7)(i) and (ii) of this section are met. Difficult to inspect parts are exe mpt from the inspection requirements of paragraphs ( c )(1) and ( 2 ) of this section. ( i ) You determine that the equipment cannot be inspected without elevating the inspecting personnel more than 2 meters above a support surface. ( ii ) You have a written pla n that requires inspection of the equipment at least once every 5 years. ( 8 ) Records . Records shall be maintained as specified in this section and in § 60.5420(c)( 12 )
.Page **128** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only **§60.5417 What are the continuous control device monitoring requirements for my storage v**  **essel or centrifugal compressor**  **affected facility?** You must meet the applicable requirements of this section to demonstrate continuous compliance for each control device used to meet emission standards for your storage vessel or centrifugal compressor af fected facility. (a) For each control device used to comply with the emission reduction standard for centrifugal compressor affected facilit ies in § 60. 5380 , You y ou must install and operate a continuous parameter monitoring system for each control device as specified in paragraphs (c) through (j) (g) of this section, except as provided for in paragraph (b) of this section. If you install and operate a flare in accordance with §60.5412(a)(3), you are exempt from the requirements of paragraphs (e) and (f) of this section.

(b) You are exempt from the monitoring requirements specified in paragraphs (c) through (j) (g) of this section for the control devices listed in paragraphs (b)(1) and (2) of this section. (1) A bo iler or process heater in which all vent streams are introduced with the primary fuel or is used as the primary fuel.Page **129** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) A boiler or process heater with a design heat input capacity equal to or greater than 44 megawatts. (c) If you are required to insta ll a continuous parameter monitoring system, You must design and operate the continuous monitoring system so that a determination can be made on whether the control device is achieving the applicable performance requirements of §60.5412. For each continuou s parameter monitoring system, you must meet the specifications and requirements in paragraphs (c)(1) through (4) of this section. (1) Each continuous parameter monitoring system must measure data values at least once every hour and record the parameter s in paragraphs (c)(1)(i) or (ii) of this section. (i) Each measured data value. (ii) Each block average value for each 1

- hour period or shorter periods calculated from all measured data values during each period. If values are measured more frequently t han once per minute, a single value for each minute may be used to calculate the hourly (or shorter period) block average instead of all measured values. (2) You must prepare a site

- specific monitoring plan that addresses the monitoring system design, dat a collection, and the quality assurance and quality control elements outlined in paragraphs (c)(2)(i) through (v) of this section. You must install, calibrate, operate, and maintain each continuousPage **130** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only parameter monitoring system in accordance with the procedu res in your approved site

- specific monitoring plan. (i) The performance criteria and design specifications for the monitoring system equipment, including the sample interface, detector signal analyzer, and data acquisition and calculations. (ii) Samplin g interface ( e.g. , thermocouple) location such that the monitoring system will provide representative
measurements. (iii) Equipment performance checks, system accuracy audits, or other audit procedures. (iv) Ongoing operation and maintenance procedures in accordance with provisions in § 60.13(b)

. (v) Ongoing reporting and recordkeeping procedures in accordance with provisions in § 60.7(c), (d), and (f)

. (3) You must conduct the continuous parameter monitoring system equipment performance checks, system a ccuracy audits, or other audit procedures specified in the site

- specific monitoring plan at least once every 12 months. (4) You must conduct a performance evaluation of each continuous parameter monitoring system in accordance with the site

- specific monit oring plan. (d) You must install, calibrate, operate, and maintain a device equipped with a continuous recorder to measure the values of operating parameters appropriate for the control device asPage **131** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only specified in either paragraph (d)(1), (2), or (3) of this

s ection. (1) A continuous monitoring system that measures the operating parameters in paragraphs (d)(1)(i) through (viii) of this section, as applicable. (i) For a thermal vapor incinerator that demonstrates during the performance test conducted under §60 .5413 that combustion zone temperature is an accurate indicator of performance, a temperature monitoring device equipped with a continuous recorder. The monitoring device must have a minimum accuracy of ±1 percent of the temperature being monitored in °C, or ±2.5°C, whichever value is greater. You must install the temperature sensor at a location representative of the combustion zone temperature. (ii) For a catalytic vapor incinerator, a temperature monitoring device equipped with a continuous recorder. Th e device must be capable of monitoring temperature at two locations and have a minimum accuracy of ±1 percent of the temperature being monitored in °C, or ±2.5°C, whichever value is greater. You must install one temperature sensor in the vent stream at the nearest feasible point to the catalyst bed inlet, and you must install a second temperature sensor in the vent stream at the nearest feasible point to the catalyst bed outlet.Page **132** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iii) For a flare, a heat sensing monitoring device equipped with a continuous recorder that indicates the continuous ignition of the pilot flame. (iv) For a boiler or process heater, a temperature monitoring device equipped with a continuous recorder. The temperature monitoring device must have a minimum accuracy of ±1 percent of the temperature being monitored in °C, or ±2.5°C, whichever value is greater. You must install the temperature sensor at a location representative of the combustion zone temperature. (v) For a condenser, a temperature monitoring device equipped with a continuous recorder. The temperature monitoring device must have a minimum accuracy of ±1 percent of the temperature being monitored in °C, or ±2.8°C, whichever value is greater. You must install the temperature sensor at a location in the exhaust vent str eam from the condenser. (vi) For a regenerative

- type carbon adsorption system, a continuous monitoring system that meets the specifications in paragraphs (d)(1)(vi)(A) and (B) of this section. ( A ) The continuous parameter monitoring system must measure and record the average total regeneration stream mass flow or volumetric flow during each carbon bed regeneration cycle. The flow sensor must have a measurement sensitivity of 5 percent of the flow rate or 10 cubic feet per minute, whichever is greater.Page **133** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Yo u must check the mechanical connections for leakage at least every month, and you must perform a visual inspection at least every 3 months of all components of the flow continuous parameter monitoring system for physical and operational integrity and all e lectrical connections for oxidation and galvanic corrosion if your flow continuous parameter monitoring system is not equipped with a redundant flow sensor; and ( B ) The continuous parameter monitoring system must measure and record the average carbon bed temperature for the duration of the carbon bed steaming cycle and measure the actual carbon bed temperature after regeneration and within 15 minutes of completing the cooling cycle. The temperature monitoring device must have a minimum accuracy of ±1 perce nt of the temperature being monitored in °C, or ±2.5°C, whichever value is greater. (vii) For a nonregenerative

- type carbon adsorption system, you must monitor the design carbon replacement interval established using a performance test performed as specif ied in §60.5413(b). The design carbon replacement interval must be based on the total carbon working capacity of the control device and source operating schedule. (viii) For a combustion control device whose model is tested under §60.5413(d) , a continuou s monitoring system meeting the requirements of paragraphs (d)(1)(viii)(A) and (B) of this section.Page **134** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (A) The continuous monitoring system must measure gas flow rate at the inlet to the control device. The monitoring instrument must have an accuracy of ±2 p ercent or better. The flow rate at the inlet to the combustion device must not exceed the maximum or minimum flow rate determined by the manufacturer.

(B) A monitoring device that continuously indicates the presence of the pilot flame while emissions are routed to the control device

. heat sensing monitoring device equipped with a continuous recorder that indicates the continuous ignition of the pilot flame. (2) An or ganic monitoring device equipped with a continuous recorder that measures the concentration level of organic compounds in the exhaust vent stream from the control device A continuous monitoring system that measures the concentration level of organic compoun ds in the exhaust vent stream from the control device using an organic monitoring device equipped with a continuous recorder . The monitor must meet the requirements of Performance Specification 8 or 9 of 40 CFR part 60, appendix B. You must install, calibr ate, and maintain the monitor according to the manufacturer's specifications. (3) A continuous monitoring system that measures operating parameters other than those specified in paragraph (d)(1) or (2)Page **135** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only of this section, upon approval of the Administrator a s specified in § 60.13(i)

. (e) You must calculate the daily average value for each monitored operating parameter for each operating day, using the data recorded by the monitoring system, except for inlet gas flow rate . If the emissions unit operation is co ntinuous, the operating day is a 24

- hour period. If the emissions unit operation is not continuous, the operating day is the total number of hours of control device operation per 24

- hour period. Valid data points must be available for 75 percent of the
ope rating hours in an operating day to compute the daily
average. (f) For each operating parameter monitor installed in accordance with the requirements of paragraph (d) of this section, you must comply with paragraph (f)(1) of this section for all control d evices. When condensers are installed, you must also comply with paragraph (f)(2) of this section. (1) You must establish a minimum operating parameter value or a maximum operating parameter value, as appropriate for the control device, to define the cond itions at which the control device must be operated to continuously achieve the applicable performance requirements of §60.5412(a). You must establish each minimum or maximum operating parameter value as specified in paragraphs (f)(1)(i) through (iii) of t his section.Page **136** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i) If you conduct performance tests in accordance with the requirements of §60.5413(b) to demonstrate that the control device achieves the applicable performance requirements specified in §60.5412(a), then you must establish the minimum
oper ating parameter value or the maximum operating parameter value based on values measured during the performance test and supplemented, as necessary, by a condenser design analysis or control device manufacturer recommendations or a combination of both. (ii ) If you use a condenser design analysis in accordance with the requirements of §60.5413(c) to demonstrate that the control device achieves the applicable performance requirements specified in §60.5412(a), then you must establish the minimum operating para meter value or the maximum operating parameter value based on the condenser design analysis and supplemented, as necessary, by the condenser manufacturer's recommendations. (iii) If you operate a control device where the performance test requirement was m et under §60.5413(d) to demonstrate that the control device achieves the applicable performance requirements specified in §60.5412(a), then you r control device inlet gas flow rate must not exceed the maximum or minimum inlet gas flow rate determined you m ust establish the maximum inlet gas flow rate based on the performance test and supplemented, as
necessary, by the manufacturer recommendations

.Page **137** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (2) If you use a condenser as specified in paragraph (d)(1)(v) of this section, you must establish a condenser performance curve showing the relationship between condenser outlet temperature and condenser control efficiency, according to the requirements of paragraphs (f)(2)(i) and (ii) of this section . (i) If you conduct a performance test in accordance with th e requirements of §60.5413(b) to demonstrate that the condenser achieves the applicable performance requirements in §60.5412(a), then the condenser performance curve must be based on values measured during the performance test and supplemented
as necessary by control device design analysis, or control device manufacturer's recommendations, or a combination or both. (ii) If you use a control device design analysis in accordance with the requirements of §60.5413(c)(1) to demonstrate that the condenser achiev es the applicable performance requirements specified in §60.5412(a), then the condenser performance curve must be based on the condenser design analysis and supplemented, as necessary, by the control device manufacturer's recommendations. (g) A deviation for a given control device is determined to have occurred when the monitoring data or lack of monitoring data result in any one of the criteria specified in paragraphs (g)(1) through (g)(6) of this section being met. If you monitorPage **138** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only multiple operating param eters for the same control device during the same operating day and more than one of these operating parameters meets a deviation criterion specified in paragraphs (g)(1) through (6) of this section, then a single excursion is determined to have occurred f or the control device for that operating day. (1) A deviation occurs when the daily average value of a monitored operating parameter is less than the minimum operating parameter limit (or, if applicable, greater than the maximum operating parameter limit) established in paragraph (f)(1) of this section. (2) If you meet §60.5412(a)(2), a deviation occurs when the 365

- day average condenser efficiency calculated according to the requirements specified in §60.5415(e)(8)(iv) is less than 95.0 percent. (3) If you meet §60.5412(a)(2) and you have less than 365 days of data, a deviation occurs when the average condenser efficiency calculated according to the procedures specified in §60.5415(e)(8)(iv)(A) or (B) is less than 90.0 percent. (4) A deviation occurs when the monitoring data are not available for at least 75 percent of the operating hours in a day. (5) If the closed vent system contains one or more bypass devices that could be used to divert all or a portion of thePage **139** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only gases, vapors, or fumes from enterin g the control device, a deviation occurs when the requirements of paragraphs (g)(5)(i) and (ii) of this section are met. (i) For each bypass line subject to §60.5411(a)(3)(i)(A), the flow indicator indicates that flow has been detected and that the stream has been diverted away from the control device to the atmosphere. (ii) For each bypass line subject to §60.5411(a)(3)(i)(B), if the seal or closure mechanism has been broken, the bypass line valve position has changed, the key for the lock

- and

- key type l ock has been checked out, or the car

- seal has broken. (6) For a combustion control device whose model is tested under §60.5413(d), a deviation occurs when the conditions of paragraphs (g)(6)(i) or (ii) are met. (i) The inlet gas flow rate exceeds the max imum established during the test conducted under §60.5413(d). (ii) Failure of the monthly quarterly visible emissions test conducted under §60.5415(e)(7)(iii) § 60.5413 (e)(3) occurs. (h) For each control device used to comply with the emission reduction standard in §6 0 .5395( d ) (1) for your storage vessel affected facility , you must demonstrate continuous compliance according to paragraphs (h)(1) through (h)( 3 ) of this section. You are exempt from the requirements of this paragra ph if you install a control device model tested in accordance withPage **140** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only §60.5413(d) (2) through (10) , which meets the criteria in §60.5413(d)(11) , the reporting requirement in §60.5413(d)(1 2 ) , and meet the continuous compliance requirement in §60.5413(e). (1) For each combustion device you must conduct inspections at least once every calendar month according to paragraphs (h)(1) (i) through ( iv ) of this section. Monthly inspections must be separated by at le ast 14 calendar days. ( i ) Conduct vis ual inspections to confirm that the pilot is lit when vapors are being routed to the combustion device and that the continuous burning pilot flame operating properly

. ( ii ) Conduct inspections to monitor for visible emissions from the combustion device using section 11 of EPA Method 22, 40 CFR part 60, Appendix A

. The observation period shall be 15 minutes. Devices must be operated with no visible emissions, except for periods not to e xceed a total of 1 minute during any 15 minute period

. ( iii) Conduct olfactory, visual and auditory inspections of all equipment associated with the combustion device to ensure system integrity. (iv) For any absence of pilot flame, or other ind ication of smoking or improper equipment operation ( e.g. , visual, audible, or olfactory), you must ensure the equipment is returned to proper operation as soon as practicable after the event occurs.Page **141** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only At a minimum, you must perform the procedures specified i n paragraphs (h)(1)(iv)(A) and (B) of this section. (A) You must check the air vent for obstruction. I f an obstruction is observed, you must clear the obstruction as soon as practicable. (B ) You must check for liquid reaching combustor

. (2) For each vapor recovery device, you must c onduct inspections at least once every calendar month to ensure physical integrity of the control device according to the manufacturer’s instructions . Monthly inspections must be separated by at least 14 calendar days. (3) Each control device must be operated following the manufacturer’s written ope rating instructions, procedures and maintenance schedule to ensure good air pollution control practices for minimizing emissions. Records of the manufacturer’s written operating i nstructions, procedures, and maintenance schedule must be maintained onsite as specified in §60.5420( c)(14)
. **§60.5420 What are my notification, rep**  **orting, and recordkeeping requirements?**  (a) You must submit the notifications required in §60.7(a)(1) and (4), and according to paragraphs (a)(1) and (2) through (3) of this section , if you own or operate one or more of the affected facilities specified in §60.5365 that wasPage **142** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only constructed, modified, or reconstructed during the reporting period

. (1) If you own or operate a gas well, pneumatic controller , centrifugal compressor, reciprocating compressor or storage vessel affected facility you are not required to submit the notifications required in §60.7(a)(1), (3) , and (4). (2) (i) If you own or operate a gas well affected facility, you must submit a notification to the Administrator no later than 2 days prior to the commencement of each well completion operat ion listing the anticipated date of the well completion operation. The notification shall include contact information for the owner or operator; the API well number, the latitude and longitude coordinates for each well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983 ; and the planned date of the beginning of flowback

. You may submit the notification in writing or in electronic format. (ii) If you are subject to state regulations that require advance notification of well completions and you have met those notification requirements, the n you are considered to have met the advance notification requirements of paragraph (a)(2)(i) of this section. (3) You must submit a notification identifyi ng each Group 1 storage vessel by October 15, 2013. The notification mustPage **143** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only contain the location of th e storage vessel , in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983

.

(b) Reporting requirements. You must submit annual reports containing the i nformation specified in paragraphs (b)(1) through (6) of this section to the Administrator and performance test reports as specified in paragraph (b)(7) or (8) of this section . The initial annual report is due no later than 30 90 days after the end of the initial compliance period as determined according to §60.5410 . Subsequent annual reports are due on no later than the same date each year as the initial annual report. If you own or operate more than one affected facility, you may submit one report for mu ltiple affected facilities provided the report contains all of the information required as specified in paragraphs (b)(1) through (6) of this section. Annual reports may coincide with title V reports as long as all the required elements of the annual repor t are included. You may arrange with the Administrator a common schedule on which reports required by this part may be submitted as long as the schedule does not extend the reporting period. (1) The general information specified in paragraphs (b)(1)(i) t hrough ( iv ) of this section.Page **144** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (i) The company name and address of the affected facility. (ii) An identification of each affected facility being included in the annual report. (iii) Beginning and ending dates of the reporting period. (iv) A certificatio n by a responsible official of truth, accuracy, and completeness. This certification shall state that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. (2) Fo r each gas well affected facility, the information in paragraphs (b)(2)(i) through (ii) of this section. (i) Records of each well completion operation as specified in paragraph (c)(1)(i) through (iv) of this section for each gas well affected facility co nducted during the reporting period . In lieu of submitting the records specified in paragraph (c)(1)(i) through (iv), the owner or operator may submit a list of the well completions with hydraulic fracturing completed during the reporting period and the re cords required by paragraph (c)(1)(v) of this section for each well completion. (ii) R ecord s of deviations specified in paragraph (c)(1)(ii) of this section that occurred during the reporting period

.Page **145** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (3) For each centrifugal compressor affected facilit y , the information specified in paragraphs (b)(3)(i) and (ii) of this section

. (i) An identification of each centrifugal compressor using a wet seal system constructed, modified or reconstructed during the reporting period. (ii) Records of deviations spe cified in paragraph (c)(2) of this section that occurred during the reporting period. (iii) If required to comply with §60.5380(a)(1), the records of closed vent system and cover inspections specified in paragraph s (c)(6) through ( 14 ) of this section. (4 ) For each reciprocating compressor affected facility, the information specified in paragraphs (b)(4)(i) through ( ii ) of this section. (i) The cumulative number of hours or operation or the number of months since initial startup, **[INSERT DATE 60 DAYS** 
**AFT ER DATE**  **OF PUBLICATION IN THE FEDERAL REGISTER]** , or since the previous reciprocating compressor rod packing replacement, whichever is later. (ii) Records of deviations specified in paragraph (c)(3)(iii) of this section that occurred during the reporting period.Page **146** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (5) For each pneumatic controller affected facility, the information specified in paragraphs (b)(5)(i) through ( v iii ) of this section. (i) An identification of each pneumatic controller constructed, modified or reconstructed during the reporting period, including the identification information specified in §60.5390(b)(2) or §60.5390(c)(2). ( ii ) If applicable, documentation that the use of pneumatic controller affected facilities with a natural gas bleed rate greater than 6 standard cubic feet per hour are required and the reasons why. (iii) Records of deviations specified in paragraph (c)(4)(v) of this section that occurred during the reporting period. (6) For each sto rage vessel affected facility, the information in paragraphs (b)(6)(i) throug h ( iii ) of this section. (i) An identification , including the location, of each storage vessel affected fa cility with VOC emissions greater than 6 tpy constructed, modified or reconstructed during the reporting period. The location of the storage vessel shall be in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983

.Page **147** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only ( ii ) Documentation of that the VOC emission rate determination according to the require ments is less than 6 tpy for meeting the requirements in §60.5395 (b) or ( a c ) or as required in §60.5395(d)(2)

. (iii) Records of deviations specified in paragraph (c)(5)(iii) of this section that occurred during the reporting period. ( 7 ) (i) Within 60 da ys after the date of completing each performance test (see §60.8 of this part ) as required by this subpart , except testing conducted by the manufacturer as specified in § 60.5413(d), you must submit the results of the performance tests required by this subp art to the EPA as follows. You must use the latest version of the to EPA’s WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA’s Central Data Exchange (CDX) (www.epa.gov/cdx). Performance te st data must be submitted in the file format generated through use of EPA’s Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/index.html ) existing at the time of th e performanc e test to generate a submission package file, which documents the performance test. You must then submit the file generated by the ERT through the EPA’s Compliance and Emissions Data Reporting Interface (CEDRI), which can be accessed by logging in to the EPA's Central Data Exchange (CDX)Page **148** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (https://cdx.epa.gov/). Only data collected using test methods supported by the ERT as listed on the ERT website are subject to this requirement for submitting reports electronically to WebFIRE . Owners or operators who cl aim that some of the information being submitted for performance tests is confidential business information (CBI) must submit a complete ERT file including information claimed to be CBI on a compact disk or other commonly used electronic storage media (inc luding, but not limited to, flash drives) to EPA. The electronic media must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404

- 02, 4930 Old Page Rd., Durham, NC 27703. The same ERT file with th e CBI omitted must be submitted to EPA via CDX as described earlier in this paragraph. At the discretion of the delegated authority, you must also submit these reports, including the confidential business information, to the delegated authority in the form at specified by the delegated authority

. For any performance test conducted using test methods that are not listed on the ERT website, the owner or operator shall submit the results of the performance test to the Administrator at the appropriate address li sted in §60.4. (ii) All reports , except as specified in paragraph (b)(8) of this section, required by this subpart not subject to the requirements in paragraph ( a ) ( 2 )(i) of this section must be sentPage **149** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only to the Administrator at the appropriate address listed in § 6 0
. 4 of this part . The Administrator or the delegated authority may request a report in any form suitable for the specific case ( e.g. , by commonly used electronic media such as Excel spreadsheet, on CD or hard copy). The Administrator retains the right to require submittal of reports subject to paragraph ( a ) ( 2 )(i) of this section in paper format. (8) For enclosed combustors tested by the manufacturer in accordance with §60.5413(d ), an electronic copy of the performance test results required by §60.5413(d) shall be submitted via email to Oil_and_Gas_PT@EPA.GOV unless the test results for that model of combustion control device are posted at the following website: epa.gov/airquality /oilandgas/. (c) Recordkeeping requirements

. You must maintain the records identified as specified in §60.7(f) and in paragraphs (c)(1) through ( 10 14 ) of this section . All records must be maintained for at least 5 years. (1) The records for each gas well affected facility as specified in paragraphs (c)(1)(i) through ( v ) of this section

. (i) Records identifying each well completion operation for each gas well affected facility; (ii) Record s of deviations in cases where well completion operations with hy draulic fracturing were not performed in compliance with the requirements specified in §60.5375.Page **150** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (iii) Records required in §60.5375(b) or (f) for each well completion operation conducted for each gas well affected facility that occurred during the reporti ng period. You must maintain the records specified in paragraphs (c)(1)(iii)(A) and (B) of this section. (A) For each gas well affected facility required to comply with the requirements of §60.5375(a), you must record: The location of the well; the API we ll number; the duration of flowback; duration of recovery to the flow line; duration of combustion; duration of venting; and specific reasons for venting in lieu of capture or combustion. The duration must be specified in hours of time. (B) For each gas w ell affected facility required to comply with the requirements of §60.5375(f), you must maintain the records specified in paragraph (c)(1)(iii)(A) of this section except that you do not have to record the duration of recovery to the flow line. (iv) For e ach gas well facility for which you claim an exception under §60.5375(a)(3), you must record: the location of the well; the API well number; the specific exception claimed; the starting date and ending date for the period the well operated under the except ion; and an explanation of why the well meets the claimed exception.Page **151** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (v) For each gas well affected facility required to comply with both §60.5375(a)(1) and (3), if you are using a digital photograph in lieu of the records required in paragraphs (c)(1)(i) through (iv) of this section, you must retain the records of the digital photograph as specified in §60.5410(a)(4)
. (2) For each centrifugal compressor affected facility, you must maintain records of deviations in cases where the centrifugal compressor w as not operated in compliance with the requirements specified in §60.5380

. (3) For each reciprocating compressors affected facility, you must maintain the records in paragraphs (c)(3)(i) through ( iii ) of this section. (i) Records of the cumulative number of hours of operation or number of months since initial startup or October 15, 2012, or the previous replacement of the reciprocating compressor rod packing, whichever is later. (ii) Records of the date and time of each reciprocating compressor rod packi ng replacement. (iii) Records of deviations in cases where the reciprocating compressor was not operated in compliance with the requirements specified in §60.5385.Page **152** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (4) For each pneumatic controller affected facility , you must maintain the records identif ied in paragraphs (c)(4)(i) through ( v ) of this section. (i) Records of the date, location and manufacturer specifications for each pneumatic controller constructed, modified or reconstructed

. (ii) Records of the demonstration that the use of pneumatic

c ontroller affected facilities with a natural gas bleed rate greater than 6 standard cubic feet per hour are required and the reasons why. (iii) If the pneumatic controller is not located at a natural gas processing plant, records of the manufacturer’s
spe cifications indicating that the controller is designed such that natural gas bleed rate is less than or equal to 6 standard cubic feet per hour. (iv) If the pneumatic controller is located at a natural gas processing plant, records of the documentation th at the natural gas bleed rate is zero. (v) Records of deviations in cases where the pneumatic controller was not operated in compliance with the requirements specified in §60.5390. (5) Except as specified in paragraph (c)(5)(v) of this section, f F or each storage vessel affected facility, you mustPage **153** of **1 76** 

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only maintain the records identified in paragraphs (c)(5)(i) through ( iv ) of this section. (i) If required to reduce emissions by complying with
§ 60.5395 , the records specified in § 60.5416 of this subpart

. ( ii) Records of the each VOC emissions determination for each that the VOC emission rate is less than 6 tpy per storage vessel affected facility required for the exemption under §60.5395 (b), ( a c ) or (d)(2) , as applicable including identification of the model or calculation methodology used to calculate the VOC emission rate

. (iii) Records of deviations in cases where the storage vessel was not operated in compliance with the requirements specified in §§60.5395, 60.5411, 60.5412 , and 60.5413. (iv) F or vessels that are skid

- mounted or permanently attached to something that is mobile ( such as trucks, railcars, barges or ships ), r ecords indicating the number of consecutive days that the vessel is located at a site in the oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment . I f a vessel is removed from a site and, within 30 days, is either returned to or replaced by another vessel at the site to serve the same or similar function, then the entire period since the original vessel was first located at the site, including the days whenPage **154** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the storage vessel was removed, will be added to the count towards the number of consecutive days. (v) You must maintain records of the identification and loca tion of each Group 1 storage vessel. If you have an event, as specified in §60.5395(b)(2), that could reasonably be expected to increase VOC emissions from your Group 1 storage vessel, you must maintain records of the VOC emissions rate deter mination. (6) Records of each closed vent system inspection required under For each storage vessel or centrifugal compressor subject to the closed vent system inspection requirements of
§ 60.5416(a)(1) for centrifugal compressors and (2) or § 60.5416(c)(1) for st orage vessels. , records of each inspection. (7) A record of each cover inspection For each storage vessel or centrifugal compressor subject to the cover requirements of required under § 60.5416(a)(3) for centrifugal
compressors or § 60.5416( c )( 2 ) for storage vessels , a record of each inspection

. (8) If you are For each storage vessel or centrifugal
compressor subject to the bypass requirements of § 60.5416(a)(4) for centrifugal compressors or § 60.5416( c )( 3 ) for storage vessels , a record of ea ch inspection or a record each time the key is checked out or a record of each time the alarm is sounded.Page **155** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (9) For each closed vent system used to comply with this subpart that must operate with no detectable emissions, a record of the monitoring conducte d in accordance with § 60.5416(b) (13)
. (10) F or each centrifugal compressor affected facility ,

r R ecords of the schedule for carbon replacement (as determined by the design analysis requirements of §60.5413(c)(2) or (3)) and records of each carbon replaceme nt as specified in §60.5412(c)(1). (11) For each storage vessel or centrifugal compressor subject to the control device requirements of §60.5412 (a), (b), and (c) , records of minimum and maximum operating parameter values, continuous parameter monitoring s ystem data, calculated averages of continuous parameter monitoring system data, results of all compliance calculations, and results of all inspections. ( 12 ) For each cover and closed vent system installed on storage vessel affected facilities used to comply with §60.5416(c) , a record of all inspections

. ( 13 ) For each carbon adsorber installed on storage vessel affected facilities, r ecords of the schedule for carbon replacement (as determined b y the design analysis requirements of §60.5412( d )( 2 ) ) and records of each carbon replacement as specified in §60.5412(c)(1). (14) For each storage vessel affected facility subject to the control device requirements of §60.5412(c) and (d), you mustPage **156** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only maintain records of the inspections, including any corrective actions taken, the manufacturers’ operating instructions, procedures and maintenance schedule as specified in §60.5417(h)

. You must maintain records of EPA Method 22, 40 CFR part 60, Appendix A , section 11 results, which include: company, location, company representative (name of the person performing the observation), sky conditions, process unit (type of control device), clock start time, observation period duration (in minutes and seconds), a ccumulated emission time (in minutes and seconds), and clock end time. You may create your own form including the above information or use Figure 22

- 1 in EPA Method
22 , 40 CFR part 60, Appendix A

. Manufacturer’s records must be maintained onsite. **§60.5421 What are my additional recordkeeping requirements for**  **my affected facility subject to VOC requirements for onshore natural gas processing plants?**  (a) You must comply with the requirements of paragraph (b) of this section in addition to the requirements of §60.486a. (b) The following recordkeeping requirements apply to pressure relief devices subject to the requirements of §60.5401(b)(1) of this subpart. (1) When each leak is detected as specified in §60.5401(b)(2), a weatherproof and readily visibl e identification, marked with the equipment identification number,Page **157** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only must be attached to the leaking equipment. The identification on the pressure relief device may be removed after it has been repaired. (2) When each leak is detected as specified in §60 .5401(b)(2), the following information must be recorded in a log and shall be kept for 2 years in a readily accessible location: (i) The instrument and operator identification numbers and the equipment identification number. (ii) The date the leak was detected and the dates of each attempt to repair the leak. (iii) Repair methods applied in each attempt to repair the leak. (iv) ”Above 500 ppm” if the maximum instrument reading measured by the methods specified in paragraph (a) of this sectio n after each repair attempt is 500 ppm or greater. (v) ”Repair delayed” and the reason for the delay if a leak is not repaired within 15 calendar days after discovery of the leak. (vi) The signature of the owner or operator (or designate) whose dec ision it was that repair could not be effected without a process shutdown. (vii) The expected date of successful repair of the leak if a leak is not repaired within 15 days.Page **158** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (viii) Dates of process unit shutdowns that occur while the equipment is u nrepaired. (ix) The date of successful repair of the leak. (x) A list of identification numbers for equipment that are designated for no detectable emissions under the provisions of §60.482

- 4a(a). The designation of equipment subject to the provisi ons of §60.482

- 4a(a) must be signed by the owner or operator. **§60.5422 What are my additional reporting requirements for my affected facility subject to VOC requirements for onshore**  **natural gas processing plants?** (a) You must comply with the requirements of paragraphs (b) and (c) of this section in addition to the requirements of §60.487a(a), (b), (c)(2)(i) through (iv), and (c)(2)(vii) through (viii). (b) An owner or operator must include the following information in the initial semiannual report in addi tion to the information required in §60.487a(b)(1) through (4): Number of pressure relief devices subject to the requirements of §60.5401(b) except for those pressure relief devices designated for no detectable emissions under the provisions of §60.482

– 4a( a) and those pressure relief devices complying with §60.482

– 4a(c).Page **159** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only (c) An owner or operator must include the following information in all semiannual reports in addition to the information required in §60.487a(c)(2)(i) through (vi): (1) Number of pressure relief devices for which leaks were detected as required in §60.5401(b)(2); and (2) Number of pressure relief devices for which leaks were not repaired as required in §60.5401(b)(3). **§60.5423 What additional recordkeeping and reporting requirements apply**  **to my sweetening unit affected facilities at onshore natural gas processing plants?**  (a) You must retain records of the calculations and measurements required in §60.5405(a) and (b) and §60.5407(a) through (g) for at least 2 years following the date of th e measurements. This requirement is included under §60.7(d) of the General Provisions. (b) You must submit a report of excess emissions to the Administrator in your annual report if you had excess emissions during the reporting period . For the purpose of these reports, excess emissions are defined as: (1) Any 24

- hour period (at consistent intervals) during which the average sulfur emission reduction efficiency (R) is less than the minimum required efficiency (Z). (2) For any affected facility electing to comply with the provisions of §60.5407(b)(2), any 24

- hour period during whichPage **160** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only the average temperature of the gases leaving the combustion zone of an incinerator is less than the appropriate operating temperature as determined during the most recent perfor mance test in accordance with the provisions of §60.5407(b)(2). Each
24

- hour period must consist of at least 96 temperature measurements equally spaced over the 24 hours. (c) To certify that a facility is exempt from the control requirements of these stan dards, for each facility with a design capacity less that 2 LT/D of H 2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H 2 S expressed as sulfur. (d) If you elect to comply with §60.5407(e) you must keep, for the life of the facility, a record demonstrating that the facility's design capacity is less than 150 LT/D of H 2 S expressed as sulfur. (e) The requirements of paragraph (b) of this s ection remain in force until and unless the EPA, in delegating enforcement authority to a state under section 111(c) of the Act, approves reporting requirements or an alternative means of compliance surveillance adopted by such state. In that event, affect ed sources within the state will be relieved of obligation to comply with paragraph (b) of this section, provided that they comply with the requirements established by the state.Page **161** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only **§60.5425 What part of the General Provisions apply to me?** Table 3 to this su bpart shows which parts of the General Provisions in §§60.1 through 60.19 apply to you. **§60.5430 What definitions apply to this subpart?** As used in this subpart, all terms not defined herein shall have the meaning given them in the Act, in subpart A or su bpart VVa of part 60; and the following terms shall have the specific meanings given them. Acid gas means a gas stream of hydrogen sulfide (H 2 S) and carbon dioxide (CO 2 ) that has been separated from sour natural gas by a sweetening unit. Affirmative defe nse means, in the context of an enforcement proceeding, a response or defense put forward by a defendant, regarding which the defendant has the burden of proof, and the merits of which are independently and objectively evaluated in a judicial or administra tive proceeding. Alaskan North Slope means the approximately 69,000 square

mile area extending from the Brooks Range to the Arctic Ocean. API Gravity means the weight per unit volume of hydrocarbon liquids as measured by a system recommended by the Ameri can Petroleum Institute (API) and is expressed in degrees. Bleed rate means the rate in standard cubic feet per hour at which natural gas is continuously vented (bleeds) from a pneumatic controller.Page **162** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Centrifugal compressor means any machine for raising th e pressure of a natural gas by drawing in low pressure natural gas and discharging significantly higher pressure natural gas by means of mechanical rotating vanes or impellers. Screw, sliding vane, and liquid ring compressors are not centrifugal
compressor s for the purposes of this subpart. City gate means the delivery point at which natural gas is transferred from a transmission pipeline to the local gas utility. Completion combustion device means any ignition device, installed horizontally or vertically , used in exploration and production operations to combust otherwise vented emissions from completions. Compressor station means any permanent combination of one

or more compressors that move natural gas at increased pressure from fields, in transmission pipelines, or into storage. Condensate means hydrocarbon liquid separated from natural gas that condenses due to changes in the temperature, pressure, or both, and remains liquid at standard conditions

. Continuous bleed means a continuous flow of pneumat ic supply natural gas to the process control device ( e.g. , level control, temperature control, pressure control) where the supply gas pressure is modulated by the process condition, and then flows to the valve controller where the signal is compared withPage **163** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only t he process set

- point to adjust gas pressure in the valve
actuator. Custody transfer means the transfer of natural gas after processing and/or treatment in the producing operations, or from storage vessels or automatic transfer facilities or other such
equ ipment, including product loading racks, to pipelines or any other forms of transportation. Dehydrator means a device in which an absorbent directly contacts a natural gas stream and absorbs water in a contact tower or absorption column (absorber). Devia tion means any instance in which an affected source subject to this subpart, or an owner or operator of such a

source: ( 1 ) Fails to meet any requirement or obligation established by this subpart including, but not limited to, any emission limit, operating limit, or work practice standard; ( 2 ) Fails to meet any term or condition that is adopted to implement an applicable requirement in this subpart and that is included in the operating permit for any affected source required to obtain such a permit; or ( 3 ) Fails to meet any emission limit, operating limit, or work practice standard in this subpart during startup, shutdown, or malfunction, regardless o f whether or not such failure is permitted by this subpart.Page **164** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Delineation well means a well drilled in order to determine the boundary of a field or producing reservoir. Equipment means each pump, pressure relief device, open

ended valve or line, valve, and flange or other connector that is in VOC service or in wet gas service, and any device or system required by this subpart. Field gas means feedstock gas entering the natural gas processing plant. Field gas gathering means the system used transport field gas from a field to the main pipeline in the area. Flare means a thermal oxidation system using an open (without enclosure) flame. Completion combustion devices as defined in this section are not considered flares. Flow line means a pipeline used to transport oil and/or gas from the well to a processing facility, a mainline pipeline, re

injection, or other useful purpose

. Flowback means the process of allowing fluids to flow from a natural gas well following a treatment, either in preparation for a subsequent phase of treatment or in preparation for cleanup and returning the well to production. The flowback period begins when material introduced into the well during the treatment returns to the surface immediately following hydraulic fracturing or refracturing. The flowback period ends with either well shut in or when the well is producing continuously to th ePage **165** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only flow line or to a storage vessel for collection, whichever occurs first. Gas processing plant process unit means equipment assembled for the extraction of natural gas liquids from field gas, the fractionation of the liquids into natural gas products, or other operations associated with the processing of natural gas products. A process unit can operate independently if supplied with sufficient feed or raw materials and sufficient storage facilities for the products. Gas well or natural gas well means an onshore well drilled principally for production of natural gas . Group 1 storage vessel means a storage vessel, as defined in this section, that is constructed, modified or reconstructed on or after August 23, 2011, and before **[INSERT DATE OF**
**PUBLICATION I N THE FEDERAL REGISTER]** 
. Group 2 storage vessel means a storage vessel, as defined in this section, that is constructed, modified or reconstruct ed on or after **[INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER]** 
. Hydraulic fracturing or refracturing means the process of directing pressurized fluids containing any combination of water, proppant, and any added chemicals to penetrate tight forma tions, such as shale or coal formations , that subsequentlyPage **166** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only require high rate, extended flowback to expel fracture fluids and solids during completions. Hydraulic refracturing means conducting a subsequent hydraulic fracturing operation at a well that has previously undergone a hydraulic fracturing operation. In light liquid service means that the piece of equipment contains a liquid that meets the conditions specified in §60. 485a(e) or §60.5401( g )(2) of this part. In wet gas service means that a compressor or piece of equipment contains or contacts the field gas before the extraction step at a gas processing plant process unit. Intermediate h ydrocarbon liquid means any natur ally occurring, unrefined petroleum liquid.

Intermittent/snap

- action pneumatic controller means a pneumatic controller that vents non

- continuously. Liquefied natural gas unit means a unit used to cool natural gas to the point at which it is condensed in to a liquid which is colorless, odorless, non

- corrosive and non

- toxic. Low pressure gas well means a well with reservoir pressure and vertical well depth such that 0.445 times the reservoir pressure (in psia) minus 0.038 times the vertical well depth (in feet) minus 67.578 psia is less than the flow line pressure at the sales meter.Page **167** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Natural g as - driven pneumatic controller means a pneumatic controller powered by pressurized natural gas. Natural gas liquids means the hydrocarbons, such as ethane,
propane, butane, and pentane that are extracted from field gas. Natural gas processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both. A Joule

- Thompson valve, a dew point depression valve, or an isolated or standalone Joule

Thompson skid is not a natural gas processing plant. Natural gas transmission means the pipelines used for the long distance transport of natural gas (exc luding processing). Specific equipment used in natural gas transmission includes the land, mains, valves, meters, boosters, regulators, storage vessels, dehydrators, compressors, and their driving units and appurtenances, and equipment used for transportin g gas from a production plant, delivery point of purchased gas, gathering system, storage area, or other wholesale source of gas to one or more distribution area(s). Nonfractionating plant means any gas plant that does not fractionate mixed natural gas li quids into natural gas products.
Non

- natural gas

- driven pneumatic controller means an instrument that is actuated using other sources of power thanPage **168** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only pressurized natural gas; examples include solar, electric, and instrument air. Onshore means all faciliti es except those that are located in the territorial seas or on the outer continental shelf. Pneumatic controller means an automated instrument used for maintaining a process condition such as liquid level, pressure, delta

- pressure and temperature.
Press ure vessel means a storage vessel that is used to store liquids or gases and is designed not to vent to the atmosphere as a result of compression of the vapor headspace in the pressure vessel during filling of the pressure vessel to its design capacity.

P rocess unit means components assembled for the extraction of natural gas liquids from field gas, the fractionation of the liquids into natural gas products, or other operations associated with the processing of natural gas products. A process unit can oper ate independently if supplied with sufficient feed or raw materials and sufficient storage facilities for the products. Produced water means water that is extracted from the earth from an oil or natural gas production well, or that is separated from crud e oil, condensate, or natural gas after extraction.Page **169** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Reciprocating compressor means a piece of equipment that increases the pressure of a process gas by positive displacement, employing linear movement of the driveshaft. Reciprocating compressor rod packi ng means a series of flexible rings in machined metal cups that fit around the reciprocating compressor piston rod to create a seal limiting the amount of compressed natural gas that escapes to the atmosphere. Reduced emissions completion means a well com pletion following fracturing or refracturing where gas flowback that is otherwise vented is captured, cleaned, and routed to the flow line or collection system, re

- injected into the well or another well, used as an on

- site fuel source, or used for other us eful purpose that a purchased fuel or raw material would serve, with no direct release to the atmosphere

. Reduced sulfur compounds means H 2 S, carbonyl sulfide (COS), and carbon disulfide (CS 2 ). Responsible official means one of the following: (1) For a corporation: a president, secretary, treasurer, or vice

- president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision

- making functions for the corporation, or a duly authorized represen tative of such person if the representative is responsible for the overall operation of onePage **170** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only or more manufacturing, production, or operating facilities applying for or subject to a permit and either: (i) The facilities employ more than 250 persons or have gross annual sales or expenditures exceeding $25 million (in second quarter 1980 dollars); or (ii) The delegation of authority to such representatives is approved in advance by the permitting authority; (2) For a partnership or sole proprietorship: a gen eral partner or the proprietor, respectively; (3) For a municipality, State, Federal, or other public agency: Either a principal executive officer or ranking elected official. For the purposes of this part, a principal executive officer of a Federal agenc y includes the chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency ( e.g. , a Regional Administrator of EPA); or (4) For affected facilities : (i) The designated representative in so far as ac tions, standards, requirements, or prohibitions under title IV of the Clean Air Act or the regulations promulgated thereunder are concerned; or (ii) The designated representative for any other purposes under part 6 0.Page **171** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only Routed to a process or route to a pro cess means the emissions are conveyed via a closed vent system to any enclosed portion of a process unit where the emissions are predominantly recycled and/or consumed in the same manner as a material that fulfills the same function in the process and/or t ransformed by chemical reaction into materials that are not regulated materials and/or incorporated into a product; and/or recovered. Salable quality gas means natural gas that meets the composition, moisture, or other limits set by the purchaser of the n atural gas , regardless of whether such gas is sold

. Storage vessel means a tank or other vessel that contain s an accumulation of crude oil, condensate, intermediate hydrocarbon liquids, or produced water , and a unit that is constructed primarily of noneart hen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide s structural support and is designed to contain an accumulation of liquids or other materials . The following are not considered storage vessels: (1) Vessels that are skid

- m ounted or permanently attached
to something that is mobile ( such as trucks, railcars, barges or ships ) , and are intended to be located at a site for less than 180 consecutive days. If you do not keep or are not able to produce records, as required by §60.5 420(c)(5)(iv), showing that the vessel has been located at a site for less than 180Page **172** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only consecutive days, the vessel described herein is considered to be a storage vessel since the original vessel was first located at the site. ( 2) Process vessels such as sur ge control vessels, bottoms receive rs or knockout vessels. (3) Pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere. Sulfur production rate means the rate of liquid sulfur accumulation from the sulf ur recovery unit. Sulfur recovery unit means a process device that recovers element sulfur from acid gas. Surface site means any combination of one or more graded pad sites, gravel pad sites, foundations, platforms, or the immediate physical location upo n which equipment is physically affixed. Sweetening unit means a process device that removes hydrogen sulfide and/or carbon dioxide from the sour natural gas
stream. Total Reduced Sulfur (TRS) means the sum of the sulfur compounds hydrogen sulfide, meth yl mercaptan, dimethyl sulfide, and dimethyl disulfide as measured by Method 16 of appendix A to part 60 of this chapter. Total SO 2 equivalents means the sum of volumetric or mass concentrations of the sulfur compounds obtained by adding thePage **173** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only quantity exis ting as SO 2 to the quantity of SO 2 that would be obtained if all reduced sulfur compounds were converted to SO 2 (ppmv or kg/dscm (lb/dscf)). Underground storage vessel means a storage vessel stored below ground. Well means an oil or gas well, a hole dril led for the purpose of producing oil or gas, or a well into which fluids are injected. Well completion means the process that allows for the flow back of petroleum or natural gas from newly drilled wells to expel drilling and reservoir fluids and tests the reservoir flow characteristics, which may vent produced hydrocarbons to the atmosphere via an open pit or tank. Well completion operation means any well completion with hydraulic fracturing or refracturing occurring at a gas well affected facility. Wel l site means one or more areas that are directly disturbed during the drilling and subsequent operation of, or affected by, production facilities directly associated with any oil well, gas well, or injection well and its associated well pad. Wellhead mean s the piping, casing, tubing and connected valves protruding above the earth’s surface for an oil and/or natural gas well. The wellhead ends where the flow line connectsPage **174** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only to a wellhead valve. The wellhead does not include other equipment at the well site ex cept for any conveyance through which gas is vented to the atmosphere. Wildcat well means a well outside known fields or the first well drilled in an oil or gas field where no other oil and gas production exists

.

Table 1 to Subpart OOOO of part 60

– Req uired Minimum Initial SO 2 Emission Reduction Efficiency (Z i )

H 2 S content of acid gas (Y), % Sulfur feed rate (X), LT/D 2.0 < X < 5.0 5.0<X < 15.0 15.0<X < 300.0 X>300.0 Y > 50 79.0 88.51X 0.0101 Y 0.0125 or 99.9, whichever is smaller 20 < Y<50 79.0 88.5 1 X 0.0101 Y 0.01 25 or 97.9, whichever is smaller 97.9 10 < Y<20 79.0 88.5 1 X 0.0101 Y 0.0125 or 97.9 93.5 , whichever is smaller 93.5 93.5

Y<10 79.0 79.0 79.0 79.0

Table 2 to Subpart OOOO of part 60

– Required Minimum SO 2 Emission Reduction Efficiency (Z c )

H 2 S content of ac id gas (Y), % Sulfur feed rate (X), LT/D 2.0 < X < 5.0 5.0<X < 15.0 15.0<X < 300.0 X>300.0 Y > 50 74.0 85.35X 0.0144 Y 0.0128 or 99.9, whichever is smaller 20 < Y<50 74.0 85.35X 0.0144 Y 0.0128 or 97.9 97.5 , whichever is smaller 97.5 10 < Y<20 74.0 85.35X 0.0144 Y 0.0128 or 90.8, whichever 90.8 90.8Page **175** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only is smaller Y<10 74.0 74.0 74.0 74.0 E = The sulfur emission rate expressed as elemental sulfur, kilograms per hour (kg/hr) [pounds per hour (lb/hr)], rounded to one decimal place. R = The sulfur emission reduction efficiency ach ieved in percent, carried to one decimal place. S = The sulfur production rate, kilograms per hour (kg/hr) [pounds per hour (lb/hr)], rounded to one decimal place. X = The sulfur feed rate from the sweetening unit ( i.e. , the H 2 S in the acid gas), expressed as sulfur, Mg/D(LT/D), rounded to one decimal place. Y = The sulfur content of the acid gas from the sweetening unit, expressed as mole percent H 2 S (dry basis) rounded to one decimal place. Z = The minimum required sulfur dioxide (SO2) emission reduction efficiency, expressed as percent carried to one decimal place. Z i refers to the reduction efficiency required at the initial performance test. Z c refers to the reduction efficiency required on a continuous basis after compliance with Z i has been demonstrat ed.

Table 3 to Subpart OOOO of part 60

– Applicability of General Provisions to Subpart OOOO As stated in §60.5425, you must comply with the following applicable General Provisions:

General Provisions Citation Subject of Citation Applies to subpart? Exp lanation
§60.1 General applicability of the General Provisions Yes
§60.2 Definitions Yes Additional terms defined in §60.5430 §60.3 Units and abbreviations Yes §60.4 Address Yes §60.5 Determination of construction or modification Yes

§60.6 Review of plans YesPage **176** of **176**

3/18 /201 3 Revision Draft Deliberative Document for EPA Review Only §60.7 Notification and record keeping Yes Except that §60.7 only applies as specified in §60.5420(a). §60.8 Performance tests Yes Performance testing is required for control devices used on storage vessels and centrifugal compressors §60. 9 Availability of information Yes §60.10 State authority Yes §60.11 Compliance with standards and maintenance requirements No Requirements are specified in subpart OOOO. §60.12 Circumvention Yes §60.13 Monitoring requirements Yes Continuous monitor s are required for storage vessels §60.14 Modification Yes §60.15 Reconstruction Yes §60.16 Priority list Yes §60.17 Incorporations by reference Yes §60.18 General control device requirements Yes Except that §60.18 does not apply to flares. §60.1 9 General notification and reporting requirement Yes