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Subpart HH—National Emission Standards for Hazardous Air 

Pollutants From Oil and Natural Gas Production Facilities

§ 63.760 Applicability and designation of affected source.

(a) This subpart applies to the owners and operators of the 

emission points, specified in paragraph (b) of this section that 

are located at oil and natural gas production facilities that 

meet the specified criteria in paragraphs (a)(1) and either 

(a)(2) or (a)(3) of this section.

(1) Facilities that are major or area sources of hazardous 

air pollutants (HAP) as defined in §63.761. Emissions for major 

source determination purposes can be estimated using the maximum 

natural gas or hydrocarbon liquid throughput, as appropriate, 

calculated in paragraphs (a)(1)(i) through (iii) of this 

section. As an alternative to calculating the maximum natural 

gas or hydrocarbon liquid throughput, the owner or operator of a 

new or existing source may use the facility's design maximum

natural gas or hydrocarbon liquid throughput to estimate the 

maximum potential emissions. Other means to determine the 

facility's major source status are allowed, provided the 

information is documented and recorded to the Administrator's 

satisfaction in accordance with §63.10(b)(3). A facility that 

is determined to be an area source, but subsequently increases 

its emissions or its potential to emit above the major source 

levels (without first obtaining and complying with other 
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limitations that keep its potential to emit HAP below major 

source levels), and becomes a major source, must comply 

thereafter with all provisions of this subpart applicable to a 

major source starting on the applicable compliance date 

specified in paragraph (f) of this section. Nothing in this 

paragraph is intended to preclude a source from limiting its 

potential to emit through other appropriate mechanisms that may 

be available through the permitting authority.

(i) If the owner or operator documents, to the 

Administrator's satisfaction, a decline in annual natural gas or 

hydrocarbon liquid throughput, as appropriate, each year for the 

5 years prior to June 17, 1999, the owner or operator shall 

calculate the maximum natural gas or hydrocarbon liquid 

throughput used to determine maximum potential emissions 

according to the requirements specified in paragraph 

(a)(1)(i)(A) of this section. In all other circumstances, the 

owner or operator shall calculate the maximum throughput used to 

determine whether a facility is a major source in accordance 

with the requirements specified in paragraph (a)(1)(i)(B) of 

this section.

(A) The maximum natural gas or hydrocarbon liquid 

throughput is the average of the annual natural gas or 

hydrocarbon liquid throughput for the 3 years prior to June 17, 

1999, multiplied by a factor of 1.2.
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(B) The maximum natural gas or hydrocarbon liquid 

throughput is the highest annual natural gas or hydrocarbon 

liquid throughput over the 5 years prior to June 17, 1999, 

multiplied by a factor of 1.2.

(ii) The owner or operator shall maintain records of the 

annual facility natural gas or hydrocarbon liquid throughput 

each year and upon request submit such records to the 

Administrator. If the facility annual natural gas or 

hydrocarbon liquid throughput increases above the maximum 

natural gas or hydrocarbon liquid throughput calculated in 

paragraph (a)(1)(i)(A) or (a)(1)(i)(B) of this section, the 

maximum natural gas or hydrocarbon liquid throughput must be 

recalculated using the higher throughput multiplied by a factor 

of 1.2.

(iii) The owner or operator shall determine the maximum 

values for other parameters used to calculate emissions as the 

maximum for the period over which the maximum natural gas or 

hydrocarbon liquid throughput is determined in accordance with 

paragraph (a)(1)(i)(A) or (B) of this section. Parameters shall 

be based on either highest measured values or annual average. 

For estimating maximum potential emissions from glycol 

dehydration units, the glycol circulation rate used in the 

calculation shall be the unit’s maximum rate under its physical 
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and operational design consistent with the definition of 

potential to emit in §63.2.

(2) Facilities that process, upgrade, or store hydrocarbon 

liquids prior to the point of custody transfer where hydrocarbon 

liquids enter either the Organic Liquids Distribution (Nongasoline) or Petroleum Refineries source categories.

(3) Facilities that process, upgrade, or store natural gas 

prior to the point at which natural gas enters the natural gas 

transmission and storage source category or is delivered to a 

final end user. For the purposes of this subpart, natural gas 

enters the natural gas transmission and storage source category 

after the natural gas processing plant, when present. If no 

natural gas processing plant is present, natural gas enters the 

natural gas transmission and storage source category after the 

point of custody transfer.

(b) The affected sources for major sources are listed in 

paragraph (b)(1) of this section and for area sources in 

paragraph (b)(2) of this section.

(1) For major sources, the affected source shall comprise 

each emission point located at a facility that meets the 

criteria specified in paragraph (a) of this section and listed 

in paragraphs (b)(1)(i) through (b)(1)(iv) of this section.

(i) Each glycol dehydration unit;
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(ii) Each storage vessel with the potential for flash 

emissions;

(iii) The group of all ancillary equipment, except 

compressors, intended to operate in volatile hazardous air 

pollutant service (as defined in §63.761), which are located at 

natural gas processing plants; and

(iv) Compressors intended to operate in volatile hazardous 

air pollutant service (as defined in §63.761), which are located 

at natural gas processing plants. 

(2) For area sources, the affected source includes each 

triethylene glycol (TEG) dehydration unit located at a facility 

that meets the criteria specified in paragraph (a) of this 

section.

(c) [Reserved]

(d) The owner and operator of a facility that does not 

contain an affected source as specified in paragraph (b) of this 

section are not subject to the requirements of this subpart.

(e) Exemptions. The facilities listed in paragraphs (e)(1) 

and (e)(2) of this section are exempt from the requirements of 

this subpart. Records shall be maintained as required in 

§63.10(b)(3).

(1) A facility that exclusively processes, stores, or 

transfers black oil (as defined in §63.761) is not subject to 

the requirements of this subpart. For the purposes of this 
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subpart, a black oil facility that uses natural gas for fuel or 

generates gas from black oil shall qualify for this exemption.

(2) A major source facility, prior to the point of custody 

transfer, with a facility-wide actual annual average natural gas 

throughput less than 18.4 thousand standard cubic meters per day 

and a facility-wide actual annual average hydrocarbon liquid 

throughput less than 39,700 liters per day.

(f) The owner or operator of an affected major source shall 

achieve compliance with the provisions of this subpart by the 

dates specified in paragraphs (f)(1), and (f)(2), and (f)(7) 

through (f)(10) of this section. The owner or operator of an 

affected area source shall achieve compliance with the 

provisions of this subpart by the dates specified in paragraphs 

(f)(3) through (f)(6) of this section.

(1) Except as specified in paragraphs (f)(7) through (10)

of this section, tThe owner or operator of an affected major 

source, the construction or reconstruction of which commenced 

before February 6, 1998, shall achieve compliance with the 

applicable provisions of this subpart no later than June 17, 

2002, except as provided for in §63.6(i). The owner or operator 

of an area source, the construction or reconstruction of which 

commenced before February 6, 1998, that increases its emissions

of (or its potential to emit) HAP such that the source becomes a 
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major source that is subject to this subpart shall comply with 

this subpart 3 years after becoming a major source.

(2) Except as specified in paragraph (f)(7) through (10) of 

this section, tThe owner or operator of an affected major 

source, the construction or reconstruction of which commences on 

or after February 6, 1998, shall achieve compliance with the 

applicable provisions of this subpart immediately upon initial 

startup or June 17, 1999, whichever date is later. Area 

sources, other than production field facilities identified in 

(f)(9) of this section, the construction or reconstruction of 

which commences on or after February 6, 1998, that become major 

sources shall comply with the provisions of this standard 

immediately upon becoming a major source.

(3) The owner or operator of an affected area source, 

located in an Urban-1 county, as defined in §63.761, the 

construction or reconstruction of which commences before 

February 6, 1998, shall achieve compliance with the provisions 

of this subpart no later than the dates specified in paragraphs 

(f)(3)(i) or (ii) of this section, except as provided for in 

§63.6(i).

(i) If the affected area source is located within any UA 

plus offset and UC boundary, as defined in §63.761, the 

compliance date is January 4, 2010.
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(ii) If the affected area source is not located within any 

UA plus offset and UC boundary, as defined in §63.761, the 

compliance date is January 5, 2009.

(4) The owner or operator of an affected area source, 

located in an Urban-1 county, as defined in §63.761, the 

construction or reconstruction of which commences on or after 

February 6, 1998, shall achieve compliance with the provisions 

of this subpart immediately upon initial startup or January 3, 

2007, whichever date is later.

(5) The owner or operator of an affected area source that 

is not located in an Urban-1 county, as defined in §63.761, the 

construction or reconstruction of which commences before July 8, 

2005, shall achieve compliance with the provisions of this 

subpart no later than the dates specified in paragraphs 

(f)(5)(i) or (ii) of this section, except as provided for in 

§3.6(i).

(i) If the affected area source is located within any UA 

plus offset and UC boundary, as defined in §63.761, the 

compliance date is January 4, 2010.

(ii) If the affected area source is not located within any 

UA plus offset and UC boundary, as defined in §63.761, the 

compliance date is January 5, 2009.

(6) The owner or operator of an affected area source that 

is not located in an Urban-1 county, as defined in §63.761, the 
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construction or reconstruction of which commences on or after 

July 8, 2005, shall achieve compliance with the provisions of 

this subpart immediately upon initial startup or January 3, 

2007, whichever date is later.

(7) Each affected small glycol dehydration unit and each 

storage vessel that is not a storage vessel with the potential 

for flash emissions located at a major source, that commenced 

construction before [INSERT DATE OF PUBLICATION IN THE FEDERAL 

REGISTER] must achieve compliance no later than 3 years after 

the date of publication of the final rule in the Federal 

Register, except as provided in §63.6(i).

(8) Each affected small glycol dehydration unit and each 

storage vessel that is not a storage vessel with the potential 

for flash emissions, both as defined in §63.761, located at a 

major source, that commenced construction on or after [INSERT 

DATE OF PUBLICATION IN THE FEDERAL REGISTER] must achieve 

compliance immediately upon initial startup or the date of 

publication of the final rule in the Federal Register, whichever 

is later.

(9) A production field facility, as defined in §63.761, 

constructed before [INSERT DATE OF PUBLICATION IN THE FEDERAL 

REGISTER] that was previously determined to be an area source 

but becomes a major source (as defined in paragraph 3 of the 

major source definition in §63.761) on the date of publication 
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of the final rule in the Federal Register must achieve 

compliance no later than 3 years after the date of publication 

of the final rule in the Federal Register, except as provided in 

§63.6(i).

(10) Each large glycol dehydration unit, as defined in 

§63.761, that has complied with the provisions of this subpart 

prior to [INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER] by 

reducing its benzene emissions to less than 0.9 megagrams per 

year must achieve compliance no later than 2 years after the 

date of publication of the final rule in the Federal Register, 

except as provided in §63.6(i).

(g) The following provides owners or operators of an 

affected source at a major source with information on overlap of 

this subpart with other regulations for equipment leaks. The 

owner or operator of an affected source at a major source shall 

document that they are complying with other regulations by 

keeping the records specified in §63.774(b)(9).

(1) After the compliance dates specified in paragraph (f) 

of this section, ancillary equipment and compressors that are 

subject to this subpart and that are also subject to and 

controlled under the provisions of 40 CFR part 60, subpart KKK, 

are only required to comply with the requirements of 40 CFR part 

60, subpart KKK.
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(2) After the compliance dates specified in paragraph (f) 

of this section, ancillary equipment and compressors that are 

subject to this subpart and are also subject to and controlled 

under the provisions of 40 CFR part 61, subpart V, are only 

required to comply with the requirements of 40 CFR part 61, 

subpart V.

(3) After the compliance dates specified in paragraph (f) 

of this section, ancillary equipment and compressors that are 

subject to this subpart and are also subject to and controlled 

under the provisions of 40 CFR part 63, subpart H, are only 

required to comply with the requirements of 40 CFR part 63, 

subpart H.

(h) An owner or operator of an affected source that is a 

major source or is located at a major source and is subject to 

the provisions of this subpart is also subject to 40 CFR part 70 

or part 71 operating permit requirements. Unless otherwise 

required by law, the owner or operator of an area source subject 

to the provisions of this subpart is exempt from the permitting 

requirements established by 40 CFR part 70 or 40 CFR part 71.

§ 63.761 Definitions.

All terms used in this subpart shall have the meaning given 

them in the Clean Air Act (Act), subpart A of this part (General 

Provisions), and in this section. If the same term is defined 
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in subpart A and in this section, it shall have the meaning 

given in this section for purposes of this subpart.

Affirmative defense 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 administrative proceeding.

Alaskan North Slope means the approximately 180,000 square 

kilometer area (69,000 square mile area) extending from the 

Brooks Range to the Arctic Ocean.

Ancillary equipment means any of the following pieces of 

equipment: pumps, pressure relief devices, sampling connection 

systems, open-ended valves, or lines, valves, flanges, or other 

connectors.

API gravity means the weight per unit volume of hydrocarbon 

liquids as measured by a system recommended by the American 

Petroleum Institute (API) and is expressed in degrees.

Associated equipment, as used in this subpart and as 

referred to in section 112(n)(4) of the Act, means equipment 

associated with an oil or natural gas exploration or production 

well, and includes all equipment from the wellbore to the point 

of custody transfer, except glycol dehydration units and storage 

vessels with the potential for flash emissions.

BTEX means benzene, toluene, ethyl benzene and xylene.
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Black oil means hydrocarbon (petroleum) liquid with an 

initial producing gas-to-oil ratio (GOR) less than 0.31 cubic 

meters per liter and an API gravity less than 40 degrees.

Boiler means an enclosed device using controlled flame 

combustion and having the primary purpose of recovering and 

exporting thermal energy in the form of steam or hot water. 

Boiler also means any industrial furnace as defined in 40 CFR 

260.10.

Closed-vent system means a system that is not open to the 

atmosphere and is composed of piping, ductwork, connections, and 

if necessary, flow inducing devices that transport gas or vapor 

from an emission point to one or more control devices. If gas 

or vapor from regulated equipment is routed to a process (e.g., 

to a fuel gas system), the conveyance system shall not be 

considered a closed-vent system and is not subject to closedvent system standards.

Combustion device means an individual unit of equipment, 

such as a flare, incinerator, process heater, or boiler, used 

for the combustion of organic HAP emissions.

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, as specified 

in §63.2.
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Continuous recorder means a data recording device that 

either records an instantaneous data value at least once every 

hour or records hourly or more frequent block average values.

Control device means any equipment used for recovering or 

oxidizing HAP or volatile organic compound (VOC) vapors. Such 

equipment includes, but is not limited to, absorbers, carbon 

adsorbers, condensers, incinerators, flares, boilers, and 

process heaters. For the purposes of this subpart, if gas or 

vapor from regulated equipment is used, reused (i.e., injected 

into the flame zone of an enclosed combustion device), returned 

back to the process, or sold, then the recovery system used, 

including piping, connections, and flow inducing devices, is not 

considered to be a control device or closed-vent system.

Cover means a device which is placed on top of or over a 

material such that the entire surface area of the material is 

enclosed and sealed. A cover may have openings (such as access 

hatches, sampling ports, and gauge wells) if those openings are 

necessary for operation, inspection, maintenance, or repair of 

the unit on which the cover is installed, provided that each 

opening is closed and sealed when the opening is not in use. In 

addition, a cover may have one or more safety devices. Examples 

of a cover include, but are not limited to, a fixed-roof 

installed on a tank, an external floating roof installed on a 

tank, and a lid installed on a drum or other container.
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Custody transfer means the transfer of hydrocarbon liquids 

or natural gas: after processing and/or treatment in the 

producing operations, or from storage vessels or automatic 

transfer facilities or other such equipment, including product 

loading racks, to pipelines or any other forms of 

transportation. For the purposes of this subpart, the point at 

which such liquids or natural gas enters a natural gas 

processing plant is a point of custody transfer.

Equipment leaks means emissions of HAP from ancillary 

equipment (as defined in this section) and compressors.

Facility means any grouping of equipment where hydrocarbon 

liquids are processed, upgraded (i.e., remove impurities or 

other constituents to meet contract specifications), or stored

prior to the point of custody transfer; or where natural gas is 

processed, upgraded, or stored prior to entering the natural gas 

transmission and storage source category. For the purpose of a 

major source determination, facility (including a building, 

structure, or installation) means oil and natural gas production 

and processing equipment that is located within the boundaries 

of an individual surface site as defined in this section. 

Equipment that is part of a facility will typically be located 

within close proximity to other equipment located at the same 

facility. Pieces of production equipment or groupings of 

equipment located on different oil and gas leases, mineral fee 
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tracts, lease tracts, subsurface or surface unit areas, surface 

fee tracts, surface lease tracts, or separate surface sites, 

whether or not connected by a road, waterway, power line or 

pipeline, shall not be considered part of the same facility. 

Examples of facilities in the oil and natural gas production 

source category include, but are not limited to, well sites, 

satellite tank batteries, central tank batteries, a compressor 

station that transports natural gas to a natural gas processing 

plant, and natural gas processing plants.

Field natural gas means natural gas extracted from a 

production well prior to entering the first stage of processing, 

such as dehydration.

Fixed-roof means a cover that is mounted on a storage 

vessel in a stationary manner and that does not move with 

fluctuations in liquid level.

Flame zone means the portion of the combustion chamber in a 

combustion device occupied by the flame envelope.

Flare means a thermal oxidation system using an open flame 

(i.e., without enclosure).

Flash tank. See the definition for gas-condensate-glycol 

(GCG) separator.

Flow indicator means a device which indicates whether gas 

flow is present in a line or whether the valve position would 

allow gas flow to be present in a line.
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Gas-condensate-glycol (GCG) separator means a two- or 

three-phase separator through which the ―rich‖ glycol stream of 

a glycol dehydration unit is passed to remove entrained gas and 

hydrocarbon liquid. The GCG separator is commonly referred to 

as a flash separator or flash tank.

Gas-to-oil ratio (GOR) means the number of standard cubic 

meters of gas produced per liter of crude oil or other 

hydrocarbon liquid.

Glycol dehydration unit means a device in which a liquid 

glycol (including, but not limited to, ethylene glycol, 

diethylene glycol, or triethylene glycol) absorbent directly 

contacts a natural gas stream and absorbs water in a contact 

tower or absorption column (absorber). The glycol contacts and 

absorbs water vapor and other gas stream constituents from the 

natural gas and becomes ―rich‖ glycol. This glycol is then 

regenerated in the glycol dehydration unit reboiler. The ―lean‖ 

glycol is then recycled.

Glycol dehydration unit baseline operations means 

operations representative of the large glycol dehydration unit 

operations as of June 17, 1999 and the small glycol dehydrator

unit operations as of [INSERT DATE OF PUBLICATION IN THE FEDERAL 

REGISTER]. For the purposes of this subpart, for determining 

the percentage of overall HAP emission reduction attributable to 

process modifications, baseline operations shall be parameter 
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values (including, but not limited to, glycol circulation rate 

or glycol-HAP absorbency) that represent actual long-term 

conditions (i.e., at least 1 year). Glycol dehydration units in 

operation for less than 1 year shall document that the parameter 

values represent expected long-term operating conditions had 

process modifications not been made.

Glycol dehydration unit process vent means the glycol 

dehydration unit reboiler vent and the vent from the GCG 

separator (flash tank), if present.

Glycol dehydration unit reboiler vent means the vent 

through which exhaust from the reboiler of a glycol dehydration 

unit passes from the reboiler to the atmosphere or to a control 

device.

Hazardous air pollutants or HAP means the chemical 

compounds listed in section 112(b) of the Clean Air Act. All 

chemical compounds listed in section 112(b) of the Act need to 

be considered when making a major source determination. Only 

the HAP compounds listed in Table 1 of this subpart need to be 

considered when determining compliance.

Hydrocarbon liquid means any naturally occurring, unrefined 

petroleum liquid.

In VHAP service means that a piece of ancillary equipment 

or compressor either contains or contacts a fluid (liquid or 

gas) which has a total volatile HAP (VHAP) concentration equal 
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to or greater than 10 percent by weight as determined according 

to the provisions of §63.772(a).

In wet gas service means that a piece of equipment contains 

or contacts the field gas before the extraction of natural gas 

liquids.

Incinerator means an enclosed combustion device that is 

used for destroying organic compounds. Auxiliary fuel may be 

used to heat waste gas to combustion temperatures. Any energy 

recovery section is not physically formed into one manufactured 

or assembled unit with the combustion section; rather, the 

energy recovery section is a separate section following the 

combustion section and the two are joined by ducts or 

connections carrying flue gas. The above energy recovery 

section limitation does not apply to an energy recovery section 

used solely to preheat the incoming vent stream or combustion 

air.

Initial producing GOR means the producing standard cubic 

meters of gas per liter at the time that the reservoir pressure 

is above the bubble point pressure (or dewpoint pressure for a 

gas).

Initial startup means the first time a new or reconstructed 

source begins production. For the purposes of this subpart, 

initial startup does not include subsequent startups (as defined 
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in this section) of equipment, for example, following 

malfunctions or shutdowns.

Large glycol dehydration unit means a glycol dehydration 

unit with an actual annual average natural gas flowrate equal to 

or greater than 85 thousand standard cubic meters per day and 

actual annual average benzene emissions equal to or greater than 

0.90 Mg/yr, determined according to §63.772(b).

Major source, as used in this subpart, shall have the same 

meaning as in §63.2, except that:

(1) Emissions from any oil or gas exploration or production 

well (with its associated equipment, as defined in this 

section), and emissions from any pipeline compressor station or 

pump station shall not be aggregated with emissions from other 

similar units to determine whether such emission points or 

stations are major sources, even when emission points are in a 

contiguous area or under common control;

(2) Emissions from processes, operations, or equipment that 

are not part of the same facility, as defined in this section, 

shall not be aggregated; and

(3) For facilities that are production field facilities, 

only HAP emissions from glycol dehydration units and storage 

vessels with the potential for flash emissions shall be 

aggregated for a major source determination. For facilities 

that are not production field facilities, HAP emissions from all 
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HAP emission units shall be aggregated for a major source 

determination.

Natural gas means a naturally occurring mixture of 

hydrocarbon and nonhydrocarbon gases found in geologic 

formations beneath the earth's surface. The principal 

hydrocarbon constituent is methane.

Natural gas liquids (NGL) means the liquid hydrocarbons, 

such as ethane, propane, butane, pentane, natural gasoline, and 

condensate that are extracted from field natural gas.

Natural gas processing plant (gas plant) means any 

processing site engaged in the extraction of natural gas liquids 

from field gas, or the fractionation of mixed NGL to natural gas 

products, or a combination of both.

No detectable emissions means no escape of HAP from a 

device or system to the atmosphere as determined by:

(1) Instrument monitoring results in accordance with the 

requirements of §63.772(c); and

(2) The absence of visible openings or defects in the 

device or system, such as rips, tears, or gaps.

Operating parameter value means a minimum or maximum value 

established for a control device or process parameter which, if 

achieved by itself or in combination with one or more other 

operating parameter values, indicates that an owner or operator 

has complied with an applicable operating parameter limitation, 
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over the appropriate averaging period as specified in §63.772(f) 

or (g).

Operating permit means a permit required by 40 CFR part 70 

or part 71.

Organic monitoring device means an instrument used to 

indicate the concentration level of organic compounds exiting a 

control device based on a detection principle such as infra-red, 

photoionization, or thermal conductivity.

Primary fuel means the fuel that provides the principal 

heat input (i.e., more than 50 percent) to the device. To be 

considered primary, the fuel must be able to sustain operation 

without the addition of other fuels.

Process heater means an enclosed device using a controlled 

flame, the primary purpose of which is to transfer heat to a 

process fluid or process material that is not a fluid, or to a 

heat transfer material for use in a process (rather than for 

steam generation).

Produced water means water that is extracted from the earth 

from an oil or natural gas production well, or that is separated 

from crude oil, condensate, or natural gas after extraction.

Production field facilities means those facilities located 

prior to the point of custody transfer.

Production well means any hole drilled in the earth from 

which crude oil, condensate, or field natural gas is extracted.
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Reciprocating compressor means a piece of equipment that 

increases the pressure of a process gas by positive 

displacement, employing linear movement of the drive shaft.

Safety device means a device that meets both of the 

following conditions: it is not used for planned or routine 

venting of liquids, gases, or fumes from the unit or equipment 

on which the device is installed; and it remains in a closed, 

sealed position at all times except when an unplanned event 

requires that the device open for the purpose of preventing 

physical damage or permanent deformation of the unit or 

equipment on which the device is installed in accordance with 

good engineering and safety practices for handling flammable, 

combustible, explosive, or other hazardous materials. Examples 

of unplanned events which may require a safety device to open 

include failure of an essential equipment component or a sudden 

power outage.

Shutdown means for purposes including, but not limited to, 

periodic maintenance, replacement of equipment, or repair, the 

cessation of operation of a glycol dehydration unit, or other 

affected source under this subpart, or equipment required or 

used solely to comply with this subpart.

Small glycol dehydration unit means a glycol dehydration 

unit, located at a major source, with an actual annual average 

natural gas flowrate less than 85 thousand standard cubic meters 
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per day or actual annual average benzene emissions less than 

0.90 Mg/yr, determined according to §63.772(b).

Startup means the setting into operation of a glycol 

dehydration unit, or other affected equipment under this 

subpart, or equipment required or used to comply with this 

subpart. Startup includes initial startup and operation solely 

for the purpose of testing equipment.

Storage vessel means a tank or other vessel that is 

designed to contain an accumulation of crude oil, condensate, 

intermediate hydrocarbon liquids, or produced water and that is 

constructed primarily of non-earthen materials (e.g., wood, 

concrete, steel, plastic) that provide structural support.

Storage vessel with the potential for flash emissions means 

any storage vessel that contains a hydrocarbon liquid with a 

stock tank GOR equal to or greater than 0.31 cubic meters per 

liter and an API gravity equal to or greater than 40 degrees and 

an actual annual average hydrocarbon liquid throughput equal to 

or greater than 79,500 liters per day. Flash emissions occur 

when dissolved hydrocarbons in the fluid evolve from solution 

when the fluid pressure is reduced.

Surface site means any combination of one or more graded 

pad sites, gravel pad sites, foundations, platforms, or the 

immediate physical location upon which equipment is physically 

affixed.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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Tank battery means a collection of equipment used to 

separate, treat, store, and transfer crude oil, condensate, 

natural gas, and produced water. A tank battery typically 

receives crude oil, condensate, natural gas, or some combination 

of these extracted products from several production wells for 

accumulation and separation prior to transmission to a natural 

gas plant or petroleum refinery. A tank battery may or may not 

include a glycol dehydration unit.

Temperature monitoring device means an instrument used to 

monitor temperature and having a minimum accuracy of ±2 1

percent of the temperature being monitored expressed in °C, or 

±2.5 °C, whichever is greater. The temperature monitoring 

device may measure temperature in degrees Fahrenheit or degrees 

Celsius, or both.

Total organic compounds or TOC, as used in this subpart, 

means those compounds which can be measured according to the 

procedures of Method 18, 40 CFR part 60, appendix A.

UA plus offset and UC is defined as the area occupied by 

each urbanized area, each urban cluster that contains at least 

10,000 people, and the area located two miles or less from each 

urbanized area boundary.

Urban-1 County is defined as a county that contains a part 

of a Metropolitan Statistical Area with a population greater 

than 250,000, based on the Office of Management and Budget's 
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Standards for defining Metropolitan and Micropolitan Statistical 

Areas (December 27, 2000), and Census 2000 Data released by the 

U.S. Census Bureau.

Urbanized area refers to Census 2000 Urbanized Area, which 

is defined in the Urban Area Criteria for Census 2000 (March 15, 

2002). Essentially, an urbanized area consists of densely 

settled territory with a population of at least 50,000 people.

Urban cluster refers to a Census 2000 Urban Cluster, which 

is defined in the Urban Area Criteria for Census 2000 (March 15, 

2002). Essentially, an urban cluster consists of densely 

settled territory with at least 2,500 people but fewer than 

50,000 people.

Volatile hazardous air pollutant concentration or VHAP 

concentration means the fraction by weight of all HAP contained 

in a material as determined in accordance with procedures 

specified in §63.772(a).

§ 63.762 Startups, shutdowns, and malfunctions.

(a) The provisions set forth in this subpart shall apply at 

all times except during startups or shutdowns, during 

malfunctions, and during periods of non-operation of the 

affected sources (or specific portion thereof) resulting in 

cessation of the emissions to which this subpart applies. 

However, during the startup, shutdown, malfunction, or period of 

non-operation of one portion of an affected source, all emission 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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points which can comply with the specific provisions to which 

they are subject must do so during the startup, shutdown, 

malfunction, or period of non-operation.

(b) The owner or operator shall not shut down items of 

equipment that are required or utilized for compliance with the 

provisions of this subpart during times when emissions are being 

routed to such items of equipment, if the shutdown would 

contravene requirements of this subpart applicable to such items 

of equipment. This paragraph does not apply if the item of 

equipment is malfunctioning, or if the owner or operator must 

shut down the equipment to avoid damage due to a contemporaneous 

startup or, shutdown, or malfunction of the affected source or a 

portion thereof.

(c) During startups, and shutdowns, and malfunctions when 

the requirements of this subpart do not apply pursuant to 

paragraphs (a) and (b) of this section, the owner or operator 

shall implement, to the extent reasonably available, measures 

to prevent or minimize excess emissions to the maximum extent 

practical. For purposes of this paragraph, the term ―excess 

emissions‖ means emissions in excess of those that would have 

occurred if there were no startup,shutdown, or malfunction, and 

the owner or operator complied with the relevant provisions of 

this subpart. The measures to be taken shall be identified in 

the applicable startup, shutdown, and malfunction plan, and may 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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include, but are not limited to, air pollution control 

technologies, recovery technologies, work practices, pollution 

prevention, monitoring, and/or changes in the manner of 

operation of the source. Back-up control devices are not 

required, but may be used if available.

(d) Except as provided in paragraph (e) of this section, 

the owner or operator shall prepare a startup, shutdown, and 

malfunction plan as required in §63.6(e)(3), except that the 

plan is not required to be incorporated by reference into the 

source's title V permit as specified in §63.6(e)(3)(i). 

Instead, the owner or operator shall keep the plan on record as 

required by §63.6(e)(3)(v). The failure of the plan to 

adequately minimize emissions during startup,shutdown, or 

malfunctions does not shield an owner or operator from 

enforcement actions.

(e) Owners or operators are not required to prepare a 

startup,shutdown, and malfunction plan for any facility where 

all of the affected sources meet the exemption criteria 

specified in §63.764(e), or for any facility that is not located 

within a UA plus offset and UC boundary.

(d) In response to an action to enforce the standards set 

forth in this subpart, you may assert an affirmative defense to 

a claim for civil penalties for exceedances of such standards 

that are caused by malfunction, as defined in 40 CFR 63.2. 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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Appropriate penalties may be assessed, however, if you fail to 

meet your burden of proving all 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 limit, you must timely meet the notification 

requirements in paragraph (d)(2) of this section, and must prove 

by a preponderance of evidence that:

(i) The excess emissions:

(A) Were caused by a sudden, infrequent, and unavoidable 

failure of air pollution control and monitoring 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; and

(C) Did not stem from any activity or event that could have 

been foreseen and avoided, or planned for; and 

(D) Were not part of a recurring pattern indicative of 

inadequate design, operation, or maintenance; and 

(ii) Repairs were made as expeditiously as possible when 

the applicable emission limitations were being exceeded. Offshift and overtime labor were used, to the extent practicable to 

make these repairs; and 
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(iii) The frequency, amount and duration of the excess 

emissions (including any bypass) were minimized to the maximum 

extent practicable during periods of such emissions; and 

(iv) If the excess emissions resulted from a bypass of 

control equipment or a process, then the bypass was unavoidable 

to prevent loss of life, personal injury, or severe property 

damage; and 

(v) All possible steps were taken to minimize the impact of 

the excess emissions 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 excess 

emissions were documented by properly signed, contemporaneous 

operating logs; and 

(viii) At all times, the affected source was operated in a 

manner consistent with good practices for minimizing emissions; 

and 

(ix) A written root cause analysis has been prepared to 

determine, correct, and eliminate the primary causes of the 

malfunction and the excess emissions resulting from the 

malfunction event at issue. The analysis shall also specify, 

using best monitoring methods and engineering judgment, the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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amount of excess emissions that were the result of the 

malfunction.

(2) Notification. The owner or operator of the affected 

source experiencing exceedance of its emission limit(s) during a 

malfunction shall notify the Administrator by telephone or 

facsimile transmission as soon as possible, but no later than

two business days after the initial occurrence of the 

malfunction, if it wishes to avail itself of an affirmative 

defense to civil penalties for that malfunction. The owner or 

operator seeking to assert an affirmative defense shall also 

submit a written report to the Administrator within 45 days of 

the initial occurrence of the exceedance of the standard in this 

subpart to demonstrate, with all necessary supporting 

documentation, that it has met the requirements set forth in 

paragraph (d)(1) of this section. The owner or operator may 

seek an extension of this deadline for up to 30 additional days 

by submitting a written request to the Administrator before the 

expiration of the 45 day period. Until a request for an 

extension has been approved by the Administrator, the owner or 

operator is subject to the requirement to submit such report 

within 45 days of the initial occurrence of the exceedance. 

§ 63.763 [Reserved]

§ 63.764 General standards.
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(a) Table 2 of this subpart specifies the provisions of 

subpart A (General Provisions) of this part that apply and those 

that do not apply to owners and operators of affected sources 

subject to this subpart.

(b) All reports required under this subpart shall be sent 

to the Administrator at the appropriate address listed in 

§63.13. Reports may be submitted on electronic media.

(c) Except as specified in paragraph (e) of this section, 

the owner or operator of an affected source located at an 

existing or new major source of HAP emissions shall comply with 

the standards in this subpart as specified in paragraphs (c)(1) 

through (3) of this section.

(1) For each glycol dehydration unit process vent subject 

to this subpart, the owner or operator shall comply with the 

requirements specified in paragraphs (c)(1)(i) through (iii) of 

this section.

(i) The owner or operator shall comply with the control 

requirements for glycol dehydration unit process vents specified 

in §63.765;

(ii) The owner or operator shall comply with the monitoring 

requirements specified in §63.773; and

(iii) The owner or operator shall comply with the 

recordkeeping and reporting requirements specified in §§63.774 

and 63.775.
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(2) For each storage vessel with the potential for flash 

emissions subject to this subpart, the owner or operator shall 

comply with the requirements specified in paragraphs (c)(2)(i) 

through (iii) of this section.

(i) The control requirements for storage vessels specified 

in §63.766;

(ii) The monitoring requirements specified in §63.773; and

(iii) The recordkeeping and reporting requirements 

specified in §§63.774 and 63.775.

(3) For ancillary equipment (as defined in §63.761) and 

compressors at a natural gas processing plant subject to this 

subpart, the owner or operator shall comply with the 

requirements for equipment leaks specified in §63.769.

(d) Except as specified in paragraph (e)(1) of this 

section, the owner or operator of an affected source located at 

an existing or new area source of HAP emissions shall comply 

with the applicable standards specified in paragraph (d) of this 

section.

(1) Each owner or operator of an area source located within 

an UA plus offset and UC boundary (as defined in §63.761) shall 

comply with the provisions specified in paragraphs (d)(1)(i) 

through (iii) of this section.

(i) The control requirements for glycol dehydration unit 

process vents specified in §63.765;
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(ii) The monitoring requirements specified in §63.773; and

(iii) The recordkeeping and reporting requirements 

specified in §§63.774 and 63.775.

(2) Each owner or operator of an area source not located in 

a UA plus offset and UC boundary (as defined in §63.761) shall 

comply with paragraphs (d)(2)(i) through (iii) of this section.

(i) Determine the optimum glycol circulation rate using the 

following equation:

 

 

 

 

 

 

 

 

Where:

LOPT= Optimal circulation rate, gal/hr.

F = Gas flowrate (MMSCF/D).

I = Inlet water content (lb/MMSCF).

O = Outlet water content (lb/MMSCF).

3.0 = The industry accepted rule of thumb for a TEG-to water 

ratio (gal TEG/lb H2O).

1.15 = Adjustment factor included for a margin of safety.

(ii) Operate the TEG dehydration unit such that the actual 

glycol circulation rate does not exceed the optimum glycol 

circulation rate determined in accordance with paragraph 

(d)(2)(i) of this section. If the TEG dehydration unit is 

unable to meet the sales gas specification for moisture content 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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using the glycol circulation rate determined in accordance with 

paragraph (d)(2)(i), the owner or operator must calculate an 

alternate circulation rate using GRI–GLYCalcTM , Version 3.0 or 

higher. The owner or operator must document why the TEG 

dehydration unit must be operated using the alternate 

circulation rate and submit this documentation with the initial 

notification in accordance with §63.775(c)(7).

(iii) Maintain a record of the determination specified in 

paragraph (d)(2)(ii) in accordance with the requirements in 

§63.774(f) and submit the Initial Notification in accordance 

with the requirements in §63.775(c)(7). If operating conditions 

change and a modification to the optimum glycol circulation rate 

is required, the owner or operator shall prepare a new 

determination in accordance with paragraph (d)(2)(i) or (ii) of 

this section and submit the information specified under 

§63.775(c)(7)(ii) through (v).

(e) Exemptions. (1) The owner or operator of an area 

source is exempt from the requirements of paragraph (c)(1) and 

(d) of this section if the criteria listed in paragraph

(e)(1)(i) or (ii) of this section are met, except that the 

records of the determination of these criteria must be 

maintained as required in §63.774(d)(1).

(i) The actual annual average flowrate of natural gas to 

the glycol dehydration unit is less than 85 thousand standard 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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cubic meters per day, as determined by the procedures specified 

in §63.772(b)(1) of this subpart; or

(ii) The actual average emissions of benzene from the 

glycol dehydration unit process vent to the atmosphere are less 

than 0.90 megagram per year, as determined by the procedures 

specified in §63.772(b)(2) of this subpart.

(2) The owner or operator is exempt from the requirements 

of paragraph (c)(3) of this section for ancillary equipment (as 

defined in §63.761) and compressors at a natural gas processing 

plant subject to this subpart if the criteria listed in 

paragraph (e)(2)(i) or (ii) of this section are met, except that 

the records of the determination of these criteria must be 

maintained as required in §63.774(d)(2).

(i) Any ancillary equipment and compressors that contain or 

contact a fluid (liquid or gas) must have a total VHAP 

concentration less than 10 percent by weight, as determined by 

the procedures specified in §63.772(a); or

(ii) That ancillary equipment and compressors must operate 

in VHAP service less than 300 hours per calendar year.

(f) Each owner or operator of a major HAP source subject to 

this subpart is required to apply for a 40 CFR part 70 or part 

71 operating permit from the appropriate permitting authority. 

If the Administrator has approved a State operating permit 

program under 40 CFR part 70, the permit shall be obtained from 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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the State authority. If a State operating permit program has 

not been approved, the owner or operator of a source shall apply 

to the EPA Regional Office pursuant to 40 CFR part 71.

(g)–(h) [Reserved]

(i) In all cases where the provisions of this subpart 

require an owner or operator to repair leaks by a specified time 

after the leak is detected, it is a violation of this standard 

to fail to take action to repair the leak(s) within the 

specified time. If action is taken to repair the leak(s) within 

the specified time, failure of that action to successfully 

repair the leak(s) is not a violation of this standard. 

However, if the repairs are unsuccessful, and a leak is 

detected, and the owner or operator shall take further action as 

required by the applicable provisions of this subpart.

(j) At all times the owner or operator must operate and 

maintain any affected source, including associated air pollution 

control equipment and monitoring equipment, in a manner 

consistent with safety and good air pollution control practices 

for minimizing emissions. Determination of whether such 

operation and maintenance procedures are being used will be 

based on information available to the Administrator which may 

include, but is not limited to, monitoring results, review of 

operation and maintenance procedures, review of operation and 

maintenance records, and inspection of the source.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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§ 63.765 Glycol dehydration unit process vent standards.

(a) This section applies to each glycol dehydration unit 

subject to this subpart with an actual annual average natural 

gas flowrate equal to or greater than 85 thousand standard cubic 

meters per day and with actual average benzene glycol 

dehydration unit process vent emissions equal to or greater than 

0.90 megagrams per year, that must be controlled for HAP air

emissions as specified in either paragraph (c)(1)(i) or 

paragraph (d)(1)(i) of §63.764.

(b) Except as provided in paragraph (c) of this section, an 

owner or operator of a glycol dehydration unit process vent 

shall comply with the requirements specified in paragraphs 

(b)(1) and (b)(2) of this section.

(1) For each glycol dehydration unit process vent, the 

owner or operator shall control air emissions by either 

paragraph (b)(1)(i), or (b)(1)(ii), or (iii) of this section.

(i) The owner or operator of a large glycol dehydration 

unit, as defined in §63.761, shall connect the process vent to a 

control device or a combination of control devices through a 

closed-vent system. The closed-vent system shall be designed 

and operated in accordance with the requirements of §63.771(c). 

The control device(s) shall be designed and operated in 

accordance with the requirements of §63.771(d).
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(ii) The owner or operator of a glycol dehydration unit 

located at an area source, that must be controlled as specified 

in §63.764(d)(1)(i), shall connect the process vent to a control 

device or combination of control devices through a closed-vent 

system and the outlet benzene emissions from the control 

device(s) shall be reduced to a level less than 0.90 megagrams 

per year. The closed-vent system shall be designed and operated 

in accordance with the requirements of §63.771(c). The control 

device(s) shall be designed and operated in accordance with the 

requirements of §63.771(d), except that the performance levels 

specified in §63.771(d)(1)(i) and (ii) do not apply.

(iii) You must limit BTEX emissions from each small glycol 

dehydration unit process vent, as defined in §63.761, to the 

limit determined in Equation 1 of this section. The limit must 

be met in accordance with one of the alternatives specified in 

paragraphs (b)(1)(iii)(A) through (D) of this section.

  

 

 

 

 

 Equation 1

Where:

ELBTEX = Unit-specific BTEX emission limit, megagrams per year;

1.10x10-4= BTEX emission limit, grams BTEX/standard cubic meter 

-ppmv;

Throughput = Annual average daily natural gas throughput, 

standard cubic meters per day
Proposed Subpart HH Redline/Strikeout July 28, 2011

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Ci,BTEX = BTEX concentration of the natural gas at the inlet to 

the glycol dehydration unit, ppmv.

(A) Connect the process vent to a control device or 

combination of control devices through a closed-vent system. 

The closed vent system shall be designed and operated in 

accordance with the requirements of §63.771(c). The control 

device(s) shall be designed and operated in accordance with the 

requirements of §63.771(f).

(B) Meet the emissions limit through process modifications

in accordance with the requirements specified in §63.771(e).

(C) Meet the emissions limit for each small glycol 

dehydration unit using a combination of process modifications 

and one or more control devices through the requirements 

specified in paragraphs (b)(1)(iii)(A) and (B) of this section.

(D) Demonstrate that the emissions limit is met through 

actual uncontrolled operation of the small glycol dehydration 

unit. Document operational parameters in accordance with the 

requirements specified in §63.771(e) and emissions in accordance 

with the requirements specified in §63.772(b)(2).

(2) One or more safety devices that vent directly to the 

atmosphere may be used on the air emission control equipment 

installed to comply with paragraph (b)(1) of this section.

(c) As an alternative to the requirements of paragraph (b) 

of this section, the owner or operator may comply with one of 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 41 of ???

the requirements specified in paragraphs (c)(1) through (3) of 

this section.

(1) The owner or operator shall control air emissions by 

connecting the process vent to a process natural gas line.

(2) The owner or operator shall demonstrate, to the 

Administrator's satisfaction, that the total HAP emissions to 

the atmosphere from the large glycol dehydration unit process 

vent are reduced by 95.0 percent through process modifications, 

or a combination of process modifications and one or more 

control devices, in accordance with the requirements specified 

in §63.771(e).

(3) Control of HAP emissions from a GCG separator (flash 

tank) vent is not required if the owner or operator 

demonstrates, to the Administrator's satisfaction, that total 

HAP emissions to the atmosphere from the large glycol 

dehydration unit process vent are reduced by 95 percent or 

more.one of the levels specified in paragraph (c)(3)(i), or

(ii), or (iii) of this section, through the installation and 

operation of controls as specified in paragraph (b)(1) of this 

section.

(i) For any large glycol dehydration unit, HAP emissions 

are reduced by 95.0 percent or more.

(ii) For area source dehydration units, bBenzene emissions 

are reduced to a level less than 0.90 megagrams per year.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(iii) For each small glycol dehydration unit, BTEX 

emissions are reduced to a level less than the limit calculated 

by paragraph (b)(1)(iii) of this section.

§ 63.766 Storage vessel standards.

(a) This section applies to each storage vessel with the 

potential for flash emissions (as defined in §63.761) subject to 

this subpart.

(b) The owner or operator of a storage vessel with the 

potential for flash emissions (as defined in §63.761) shall 

comply with one of the control requirements specified in 

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

(1) The owner or operator shall equip the affected storage 

vessel with the potential for flash emissions with a cover that 

is connected, through a closed-vent system that meets the 

conditions specified in §63.771(c), to a control device or a 

combination of control devices that meets any of the conditions 

specified in §63.771(d). The cover shall be designed and 

operated in accordance with the requirements of §63.771(b).

(2) The owner or operator of a pressure storage vessel that 

is designed to operate as a closed system shall operate the 

storage vessel with no detectable emissions at all times that 

material is in the storage vessel, except as provided for in 

paragraph (c) of this section.
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(c) One or more safety devices that vent directly to the 

atmosphere may be used on the storage vessel and air emission 

control equipment complying with paragraphs (b)(1) and (2) of 

this section.

(d) This section does not apply to storage vessels for 

which the owner or operator is subject to and controlled under 

meeting the requirements specified in 40 CFR part 60, subpart 

Kb; or is meeting the requirements specified in 40 CFR part 63, 

subparts G or CC.

§§ 63.767-63.768 [Reserved]

§ 63.769 Equipment leak standards.

(a) This section applies to equipment subject to this 

subpart and specified in paragraphs (a)(1) and (2) of this 

section that is located at a natural gas processing plant and 

operates in VHAP service equal to or greater than 300 hours per 

calendar year.

(1) Ancillary equipment, as defined in §63.761; and

(2) Compressors.

(b) This section does not apply to ancillary equipment and 

compressors for which the owner or operator is meeting 

thesubject to and controlled under the requirements specified in 

subpart H of this part; or is meeting the requirements specified 

in 40 CFR part 60, subpart KKK.
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(c) For each piece of ancillary equipment and each 

compressor subject to this section located at an existing or new 

source, the owner or operator shall meet the requirements 

specified in 40 CFR part 61, subpart V, §§61.241 through 61.247, 

except as specified in paragraphs (c)(1) through (8) of this 

section, except that for valves subject to §61.247-2(b) a leak 

is detected if an instrument reading of 500 ppm or greater is 

measured.

(1) Each pressure relief device in gas/vapor service shall 

be monitored quarterly and within 5 days after each pressure 

release to detect leaks, except under the following conditions.

(i) The owner or operator has obtained permission from the 

Administrator to use an alternative means of emission limitation 

that achieves a reduction in emissions of VHAP at least 

equivalent to that achieved by the control required in this 

subpart.

(ii) The pressure relief device is located in a 

nonfractionating facility that is monitored only by non-facility 

personnel, it may be monitored after a pressure release the next 

time the monitoring personnel are on site, instead of within 5 

days. Such a pressure relief device shall not be allowed to 

operate for more than 30 days after a pressure release without 

monitoring.
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(2) For pressure relief devices, if an instrument reading 

of 10,000 parts per million or greater is measured, a leak is 

detected.

(3) For pressure relief devices, when a leak is detected, 

it shall be repaired as soon as practicable, but no later than 

15 calendar days after it is detected, unless a delay in repair 

of equipment is granted under 40 CFR 61.242–10.

(4) Sampling connection systems are exempt from the 

requirements of 40 CFR 61.242–5.

(5) Pumps in VHAP service, valves in gas/vapor and light 

liquid service, and pressure relief devices in gas/vapor service 

that are located at a nonfractionating plant that does not have 

the design capacity to process 283,000 standard cubic meters per 

day or more of field gas are exempt from the routine monitoring 

requirements of 40 CFR 61.242–2(a)(1) and 61.242–7(a), and 

paragraphs (c)(1) through (3) of this section.

(6) Pumps in VHAP service, valves in gas/vapor and light 

liquid service, and pressure relief devices in gas/vapor service 

located within a natural gas processing plant that is located on 

the Alaskan North Slope are exempt from the routine monitoring 

requirements of 40 CFR 61.242–2(a)(1) and 61.242–7(a), and 

paragraphs (c)(1) through (3) of this section.

(7) Reciprocating compressors in wet gas service are exempt 

from the compressor control requirements of 40 CFR 61.242–3.
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(8) Flares, as defined in §63.761, used to comply with this 

subpart shall comply with the requirements of §63.11(b).

§ 63.770 [Reserved]

§ 63.771 Control equipment requirements.

(a) This section applies to each cover, closed-vent system, 

and control device installed and operated by the owner or 

operator to control air emissions as required by the provisions 

of this subpart. Compliance with paragraphs (b), (c), and (d) 

of this section will be determined by review of the records 

required by §63.774 and the reports required by §63.775, by 

review of performance test results, and by inspections.

(b) Cover requirements. (1) The cover and all openings on 

the cover (e.g., access hatches, sampling ports, and gauge 

wells) shall be designed to form a continuous barrier over the 

entire surface area of the liquid in the storage vessel.

(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 unit following changes in the level of 

the material in the unit);
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(ii) To inspect or sample the material in the unit;

(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 paragraphs (c) and (d) of 

this section.

(c) Closed-vent system requirements. (1) The closed-vent 

system shall route all gases, vapors, and fumes emitted from the 

material in an HAP emissions unit to a control device that meets 

the requirements specified in paragraph (d) of this section.

(2) The closed-vent system shall be designed and operated 

with no detectable emissions.

(3) If the closed-vent system contains one or more bypass 

devices that could be used to divert all or a portion of the 

gases, vapors, or fumes from entering the control device, the 

owner or operator shall meet the requirements specified in 

paragraphs (c)(3)(i) and (c)(3)(ii) of this section.

(i) For each bypass device, except as provided for in 

paragraph (c)(3)(ii) of this section, the owner or operator 

shall either:

(A) At the inlet to the bypass device that could divert the 

stream away from the control device to the atmosphere, properly 

install, calibrate, maintain, and operate a flow indicator that 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 48 of ???

is capable of taking periodic readings and sounding an alarm 

when the bypass device is open such that the stream is being, or 

could be, diverted away from the control device to the 

atmosphere; or

(B) Secure the bypass device valve installed at the inlet 

to the bypass device in the non-diverting position using a carseal 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 (c)(3)(i) of this section.

(d) Control device requirements for sources except small 

glycol dehydration units. Owners and operators of small glycol 

dehydration units, shall comply with the control device 

requirements in paragraph (f) of this section. (1) The control 

device used to reduce HAP emissions in accordance with the 

standards of this subpart shall be one of the control devices 

specified in paragraphs (d)(1)(i) through (iii) of this section.

(i) An enclosed combustion device (e.g., thermal vapor 

incinerator, catalytic vapor incinerator, boiler, or process 

heater) that is designed and operated in accordance with one of 

the following performance requirements:

(A) Reduces the mass content of either TOC or total HAP in 

the gases vented to the device by 95.0 percent by weight or 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 49 of ???

greater as determined in accordance with the requirements of 

§63.772(e); or

(B) Reduces the concentration of either TOC or total HAP in 

the exhaust 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 §63.772(e); or

(C) For a control device that can demonstrate a uniform 

combustion zone temperature during the performance test

conducted under §63.772(e), oOperates at a minimum residence 

time of 0.5 seconds at a minimum temperature of 760°C.

(D) If a boiler or process heater is used as the control 

device, then the vent stream shall be introduced into the flame 

zone of the boiler or process heater.

(ii) A vapor recovery device (e.g., carbon adsorption 

system or condenser) or other non-destructive control device that 

is designed and operated to reduce the mass content of either 

TOC or total HAP in the gases vented to the device by 95.0 

percent by weight or greater as determined in accordance with 

the requirements of §63.772(e).

(iii) A flare, as defined in §63.761, that is designed and 

operated in accordance with the requirements of §63.11(b).

(2) [Reserved]
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 50 of ???

(3) The owner or operator shall demonstrate that a control 

device achieves the performance requirements of paragraph (d)(1) 

of this section as specified in §63.772(e).

(4) The owner or operator shall operate each control device 

in accordance with the requirements specified in paragraphs 

(d)(4)(i) and (ii) of this section.

(i) Each control device used to comply with this subpart 

shall be operating at all times when gases, vapors, and fumes 

are vented from the HAP emissions unit or units through the 

closed-vent system to the control device, as required under 

§§63.765, 63.766, and 63.769, except when maintenance or repair 

on a unit cannot be completed without a shutdown of the control 

device. An owner or operator may vent more than one unit to a 

control device used to comply with this subpart.

(ii) For each control device monitored in accordance with 

the requirements of §63.773(d), the owner or operator shall 

demonstrate compliance according to the requirements of 

§63.772(f) or (g), as applicable.

(5) For each carbon adsorption system used as a control 

device to meet the requirements of paragraph (d)(1) of this 

section, the owner or operator shall manage the carbon as 

follows:

(i) Following the initial startup of the control device, 

all carbon in the control device shall be replaced with fresh 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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carbon on a regular, predetermined time interval that is no 

longer than the carbon service life established for the carbon 

adsorption system. Records identifying the schedule for 

replacement and records of each carbon replacement shall be 

maintained as required in §63.774(b)(7)(ix). The schedule for 

replacement shall be submitted with the Notification of 

Compliance Status report as specified in §63.775(d)(5)(iv). 

Each carbon replacement must be reported in the Periodic Reports 

as specified in §63.772(e)(2)(xii).

(ii) The spent carbon removed from the carbon adsorption

system shall be either regenerated, reactivated, or burned in 

one of the units specified in paragraphs (d)(5)(ii)(A) through 

(d)(5)(ii)(G) of this section.

(A) Regenerated or reactivated in a thermal treatment unit 

for which the owner or operator has been issued a final permit 

under 40 CFR part 270 that implements the requirements of 40 CFR 

part 264, subpart X.

(B) Regenerated or reactivated in a thermal treatment unit 

equipped with and operating air emission controls in accordance 

with this section.

(C) Regenerated or reactivated in a thermal treatment unit 

equipped with and operating organic air emission controls in 

accordance with a national emissions standard for HAP under 

another subpart in 40 CFR part 61 or this part.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(D) Burned 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 part 264, 

subpart O.

(E) Burned in a hazardous waste incinerator which the owner 

or operator has designed and operates in accordance with the 

requirements of 40 CFR part 265, subpart O.

(F) Burned in a boiler or industrial furnace for which the 

owner or operator has been issued a final permit under 40 CFR 

part 270 that implements the requirements of 40 CFR part 266, 

subpart H.

(G) Burned in a boiler or industrial furnace which the 

owner or operator has designed and operates in accordance with 

the interim status requirements of 40 CFR part 266, subpart H.

(e) Process modification requirements. Each owner or 

operator that chooses to comply with §63.765(c)(2) shall meet 

the requirements specified in paragraphs (e)(1) through (e)(3) 

of this section.

(1) The owner or operator shall determine glycol 

dehydration unit baseline operations (as defined in §63.761). 

Records of glycol dehydration unit baseline operations shall be 

retained as required under §63.774(b)(10).

(2) The owner or operator shall document, to the 

Administrator's satisfaction, the conditions for which glycol 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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dehydration unit baseline operations shall be modified to 

achieve the 95.0 percent overall HAP emission reduction, or BTEX 

limit determined in §63.765(b)(1)(iii), as applicable, either 

through process modifications or through a combination of 

process modifications and one or more control devices. If a 

combination of process modifications and one or more control 

devices are used, the owner or operator shall also establish the 

percent HAPemission reduction to be achieved by the control 

device to achieve an overall HAP emission reduction of 95.0 

percent for the glycol dehydration unit process vent or, if 

applicable, the BTEX limit determined in §63.765(b)(1)(iii) for 

the small glycol dehydration unit process vent. Only 

modifications in glycol dehydration unit operations directly 

related to process changes, including but not limited to changes 

in glycol circulation rate or glycol-HAP absorbency, shall be 

allowed. Changes in the inlet gas characteristics or natural 

gas throughput rate shall not be considered in determining the 

overall HAP emission reduction due to process modifications.

(3) The owner or operator that achieves a 95.0 percent HAP 

emission reduction or meets the BTEX limit determined in 

§63.765(b)(1)(iii), as applicable, using process modifications 

alone shall comply with paragraph (e)(3)(i) of this section. 

The owner or operator that achieves a 95.0 percent HAP emission 

reduction or meets the BTEX limit determined in 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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§63.765(b)(1)(iii), as applicable, using a combination of 

process modifications and one or more control devices shall 

comply with paragraphs (e)(3)(i) and (e)(3)(ii) of this section.

(i) The owner or operator shall maintain records, as 

required in §63.774(b)(11), that the facility continues to 

operate in accordance with the conditions specified under 

paragraph (e)(2) of this section.

(ii) The owner or operator shall comply with the control 

device requirements specified in paragraph (d) or (f) of this 

section, as applicable, except that the emission reduction or 

limit achieved shall be the emission reduction or limit 

specified for the control device(s) in paragraph (e)(2) of this 

section.

(f) Control device requirements for small glycol 

dehydration units.

(1) The control device used to meet BTEX the emission limit 

calculated in §63.765(b)(1)(iii) shall be one of the control 

devices specified in paragraphs (f)(1)(i) through (iii) of this 

section.

(i) An enclosed combustion device (e.g., thermal vapor 

incinerator, catalytic vapor incinerator, boiler, or process 

heater) that is designed and operated to reduce the mass content 

of BTEX in the gases vented to the device as determined in 

accordance with the requirements of §63.772(e). If a boiler or 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 55 of ???

process heater is used as the control device, then the vent 

stream shall be introduced into the flame zone of the boiler or 

process heater; or

(ii) A vapor recovery device (e.g., carbon adsorption 

system or condenser) or other non-destructive control device that 

is designed and operated to reduce the mass content of BTEX in 

the gases vented to the device as determined in accordance with 

the requirements of §63.772(e); or

(iii) A flare, as defined in §63.761, that is designed and 

operated in accordance with the requirements of §63.11(b). 

(2) The owner or operator shall operate each control device 

in accordance with the requirements specified in paragraphs 

(f)(2)(i) and (ii) of this section.

(i) Each control device used to comply with this subpart 

shall be operating at all times. An owner or operator may vent 

more than one unit to a control device used to comply with this 

subpart.

(ii) For each control device monitored in accordance with 

the requirements of §63.773(d), the owner or operator shall 

demonstrate compliance according to the requirements of either 

§63.772(f) or (h).

(3) For each carbon adsorption system used as a control 

device to meet the requirements of paragraph (f)(1)(ii) of this 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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section, the owner or operator shall manage the carbon as 

required under (d)(5)(i) and (ii) of this section.

§ 63.772 Test methods, compliance procedures, and compliance 

demonstrations.

(a) Determination of material VHAP or HAP concentration to 

determine the applicability of the equipment leak standards 

under this subpart (§63.769). Each piece of ancillary equipment 

and compressors are presumed to be in VHAP service or in wet gas 

service unless an owner or operator demonstrates that the piece 

of equipment is not in VHAP service or in wet gas service.

(1) For a piece of ancillary equipment and compressors to 

be considered not in VHAP service, it must be determined that 

the percent VHAP content can be reasonably expected never to 

exceed 10.0 percent by weight. For the purposes of determining 

the percent VHAP content of the process fluid that is contained 

in or contacts a piece of ancillary equipment or compressor, you 

shall use the method in either paragraph (a)(1)(i) or paragraph 

(a)(1)(ii) of this section.

(i) Method 18 of 40 CFR part 60, appendix A, or

(ii) ASTM D6420–99 (2004), Standard Test Method for 

Determination of Gaseous Organic Compounds by Direct Interface 

Gas Chromatography-Mass Spectrometry (incorporated by reference—

see §63.14), provided that the provisions of paragraphs 

(a)(1)(ii)(A) through (D) of this section are followed:
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(A) The target compound(s) are those listed in section 1.1 

of ASTM D6420–99 (2004);

(B) The target concentration is between 150 parts per 

billion by volume and 100 parts per million by volume;

(C) For target compound(s) not listed in Table 1.1 of ASTM 

D6420–99 (2004), but potentially detected by mass spectrometry, 

the additional system continuing calibration check after each 

run, as detailed in section 10.5.3 of ASTM D6420–99 (2004), is 

conducted, met, documented, and submitted with the data report, 

even if there is no moisture condenser used or the compound is 

not considered water soluble; and

(D) For target compound(s) not listed in Table 1.1 of ASTM 

D6420–99 (2004), and not amenable to detection by mass 

spectrometry, ASTM D6420–99 (2004) may not be used.

(2) For a piece of ancillary equipment and compressors to 

be considered in wet gas service, it must be determined that it 

contains or contacts the field gas before the extraction of 

natural gas liquids.

(b) Determination of glycol dehydration unit flowrate, or

benzene emissions, or BTEX emissions. The procedures of this 

paragraph shall be used by an owner or operator to determine 

glycol dehydration unit natural gas flowrate, or benzene 

emissions, or BTEX emissions. to meet the criteria for an 

exemption from control requirements under §63.764(e)(1).
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(1) The determination of actual flowrate of natural gas to 

a glycol dehydration unit shall be made using the procedures of 

either paragraph (b)(1)(i) or (b)(1)(ii) of this section.

(i) The owner or operator shall install and operate a 

monitoring instrument that directly measures natural gas 

flowrate to the glycol dehydration unit with an accuracy of plus 

or minus 2 percent or better. The owner or operator shall 

convert annual natural gas flowrate to a daily average by 

dividing the annual flowrate by the number of days per year the 

glycol dehydration unit processed natural gas.

(ii) The owner or operator shall document, to the 

Administrator's satisfaction, that the actual annual average 

natural gas flowrate to the glycol dehydration unit is less than 

85 thousand standard cubic meters per day.

(2) The determination of actual average benzene or BTEX 

emissions from a glycol dehydration unit shall be made using the 

procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this 

section. Emissions shall be determined either uncontrolled, or 

with federally enforceable controls in place.

(i) The owner or operator shall determine actual average 

benzene or BTEX emissions using the model GRI-GLYCalcTM , Version 

3.0 or higher, and the procedures presented in the associated 

GRI-GLYCalcTM Technical Reference Manual. Inputs to the model 

shall be representative of actual operating conditions of the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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glycol dehydration unit and may be determined using the 

procedures documented in the Gas Research Institute (GRI) report 

entitled ―Atmospheric Rich/Lean Method for Determining Glycol 

Dehydrator Emissions‖ (GRI–95/0368.1); or

(ii) The owner or operator shall determine an average mass 

rate of benzene or BTEX emissions in kilograms per hour through 

direct measurement using the methods in §63.772(a)(1)(i) or 

(ii), or an alternative method according to §63.7(f). Annual 

emissions in kilograms per year shall be determined by 

multiplying the mass rate by the number of hours the unit is 

operated per year. This result shall be converted to megagrams 

per year.

(c) No detectable emissions test procedure. (1) The no 

detectable emissions test procedure shall be conducted in 

accordance with Method 21, 40 CFR part 60, appendix A.

(2) The detection instrument shall meet the performance 

criteria of Method 21, 40 CFR part 60, appendix A, except that 

the instrument response factor criteria in section 3.1.2(a) of 

Method 21 shall be for the average composition of the fluid and 

not for each individual organic compound in the stream.

(3) The detection instrument shall be calibrated before use 

on each day of its use by the procedures specified in Method 21, 

40 CFR part 60, appendix A.

(4) Calibration gases shall be as follows:
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(i) Zero air (less than 10 parts per million by volume 

hydrocarbon in air); and

(ii) A mixture of methane in air at a concentration less 

than 10,000 parts per million by volume.

(5) An owner or operator may choose to adjust or not adjust 

the detection instrument readings to account for the background 

organic concentration level. If an owner or operator chooses to 

adjust the instrument readings for the background level, the 

background level value must be determined according to the 

procedures in Method 21 of 40 CFR part 60, appendix A.

(6)(i) Except as provided in paragraph (c)(6)(ii) of this 

section, the detection instrument shall meet the performance 

criteria of Method 21 of 40 CFR part 60, appendix A, except the 

instrument response factor criteria in section 3.1.2(a) of 

Method 21 shall 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 which are not organic hazardous air pollutants or 

volatile organic compounds, the average stream response factor 

shall be calculated on an inert-free basis.

(ii) If no instrument is available at the facility that 

will meet the performance criteria specified in paragraph 

(c)(6)(i) of this section, the instrument readings may be 

adjusted by multiplying by the average response factor of the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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process fluid, calculated on an inert-free basis as described in 

paragraph (c)(6)(i) of this section.

(7) An owner or operator must determine if a potential leak 

interface operates with no detectable emissions using the 

applicable procedure specified in paragraph (c)(7)(i) or 

(c)(7)(ii) of this section.

(i) If an owner or operator chooses not to adjust the 

detection instrument readings for the background organic 

concentration level, then the maximum organic concentration 

value measured by the detection instrument is compared directly 

to the applicable value for the potential leak interface as 

specified in paragraph (c)(8) of this section.

(ii) If an owner or operator chooses to adjust the 

detection instrument readings for the background organic 

concentration level, 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 (c)(5) of this section is compared with 

the applicable value for the potential leak interface as 

specified in paragraph (c)(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 (c)(7) of this 

section, is less than 500 parts per million by volume.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(d) [Reserved] Test procedures and compliance 

demonstrations for small glycol dehydration units. This 

paragraph applies to the test procedures for small dehydration 

units.

(1) If the owner or operator is using a control device to 

comply with the emission limit in §63.765(b)(1)(iii), the 

requirements of paragraph (e) of this section apply. Compliance 

is demonstrated using the methods specified in paragraph (f) of 

this section.

(2) If no control device is used to comply with the 

emission limit in §63.765(b)(1)(iii), the owner or operator must 

determine the glycol dehydration unit BTEX emissions as 

specified in paragraphs (d)(2)(i) through (iii) of this section. 

Compliance is demonstrated if the BTEX emissions determined as 

specified in paragraphs (d)(2)(i) through (iii) are less than 

the emission limit calculated using the equation in 

§63.765(b)(1)(iii).

(i) Method 1 or 1A, 40 CFR part 60, appendix A, as 

appropriate, shall be used for selection of the sampling sites 

at the outlet of the glycol dehydration unit process vent. Any 

references to particulate mentioned in Methods 1 and 1A do not 

apply to this section.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(ii) The gas volumetric flowrate shall be determined using 

Method 2, 2A, 2C, or 2D, 40 CFR part 60, appendix A, as 

appropriate.

(iii) The BTEX emissions from the outlet of the glycol 

dehydration unit process vent shall be determined using the 

procedures specified in paragraph (e)(3)(v) of this section. As 

an alternative, the mass rate of BTEX at the outlet of the 

glycol dehydration unit process vent may be calculated using the 

model GRI-GLYCalcTM , Version 3.0 or higher, and the procedures 

presented in the associated GRI-GLYCalcTM Technical Reference 

Manual. Inputs to the model shall be representative of actual 

operating conditions of the glycol dehydration unit and shall be 

determined using the procedures documented in the Gas Research 

Institute (GRI) report entitled ―Atmospheric Rich/Lean Method 

for Determining Glycol Dehydrator Emissions‖ (GRI–95/0368.1). 

When the BTEX mass rate is calculated for glycol dehydration 

units using the model GRI-GLYCalcTM , all BTEX measured by Method 

18, 40 CFR part 60, appendix A, shall be summed.

(e) Control device performance test procedures. This 

paragraph applies to the performance testing of control devices. 

The owners or operators shall demonstrate that a control device 

achieves the performance requirements of §63.771(d)(1) ,or 

(e)(3)(ii) or (f)(1) using either a performance test as 

specified in paragraph (e)(3) of this section. Owners or 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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operators using a condenser have the option to use or a design 

analysis as specified in paragraph (e)(4) of this section. The 

owner or operator may elect to use the alternative procedures in 

paragraph (e)(5) of this section for performance testing of a 

condenser used to control emissions from a glycol dehydration 

unit process vent. As an alternative to conducting a 

performance test under this section for combustion control 

devices, a control device that can be demonstrated to meet the 

performance requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1) 

through a performance test conducted by the manufacturer, as

specified in paragraph (h) of this section, can be used.

(1) The following control devices are exempt from the 

requirements to conduct performance tests and design analyses 

under this section:

(i) Except as specified in paragraph (e)(2) of this 

section, a flare, as defined in §63.761, that is designed and 

operated in accordance with §63.11(b);

(ii) Except for control devices used for small glycol 

dehydration units, aA boiler or process heater with a design 

heat input capacity of 44 megawatts or greater;

(iii) Except for control devices used for small glycol 

dehydration units, aA boiler or process heater into which the 

vent stream is introduced with the primary fuel or is used as 

the primary fuel;
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(iv) Except for control devices used for small glycol 

dehydration units, A a boiler or process heater burning 

hazardous waste for which the owner or operator has either been 

issued a final permit under 40 CFR part 270 and complies with 

the requirements of 40 CFR part 266, subpart H; or has certified 

compliance with the interim status requirements of 40 CFR part 

266, subpart H;

(v) Except for control devices used for small glycol 

dehydration units, aA hazardous waste incinerator for which the 

owner or operator has been issued a final permit under 40 CFR 

part 270 and complies with the requirements of 40 CFR part 264, 

subpart O; or has certified compliance with the interim status 

requirements of 40 CFR part 265, subpart O.

(vi) A control device for which a performance test was 

conducted for determining compliance with a regulation 

promulgated by the EPA and the test was conducted using the same 

methods specified in this section and either no process changes 

have been made since the test, or the owner or operator can 

demonstrate that the results of the performance test, with or 

without adjustments, reliably demonstrate compliance despite 

process changes.

(2) An owner or operator shall design and operate each 

flare, as defined in §63.761, in accordance with the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 66 of ???

requirements specified in §63.11(b) and in paragraphs (e)(2)(i) 

and (e)(2)(ii) of this section.

(i) tThe compliance determination shall be conducted using 

Method 22 of 40 CFR part 60, appendix A, to determine visible 

emissions.

(ii) An owner or operator is not required to conduct a 

performance test to determine percent emission reduction or 

outlet organic HAP or TOC, or BTEX concentration when a flare is 

used.

(3) For a performance test conducted to demonstrate that a 

control device meets the requirements of §63.771(d)(1), or 

(e)(3)(ii) or (f)(1), the owner or operator shall use the test 

methods and procedures specified in paragraphs (e)(3)(i) through 

(iv) of this section. The performance test results shall be 

submitted in the Notification of Compliance Status Report as 

required in §63.775(d)(1)(ii).The initial and periodic 

performance tests shall be conducted according to the schedule 

specified in paragraph (e)(3)(vi) of this section.

(i) Method 1 or 1A, 40 CFR part 60, appendix A, as 

appropriate, shall be used for selection of the sampling sites 

in paragraphs (e)(3)(i)(A) and (B) of this section. Any 

references to particulate mentioned in Methods 1 and 1A do not 

apply to this section.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(A) To determine compliance with the control device percent 

reduction requirement specified in §63.771(d)(1)(i)(A), 

(d)(1)(ii) or (e)(3)(ii), sampling sites shall be located at the 

inlet of the first control device, and at the outlet of the 

final control device.

(B) To determine compliance with the enclosed combustion 

device total HAP concentration limit specified in 

§63.771(d)(1)(i)(B), or the BTEX emission limit specified in 

§63.765(b)(1)(iii), the sampling site shall be located at the 

outlet of the combustion device.

(ii) The gas volumetric flowrate shall be determined using 

Method 2, 2A, 2C, or 2D, 40 CFR part 60, appendix A, as 

appropriate.

(iii) To determine compliance with the control device 

percent reduction performance requirement in 

§63.771(d)(1)(i)(A), (d)(1)(ii), and (e)(3)(ii), the owner or 

operator shall use one of the following methods: Method 18, 40 

CFR part 60, appendix A; Method 25A, 40 CFR part 60, appendix A; 

ASTM D6420–99 (2004), as specified in §63.772(a)(1)(ii); or any 

other method or data that have been validated according to the 

applicable procedures in Method 301, 40 CFR part 63, appendix A. 

The following procedures shall be used to calculate percent 

reduction efficiency:
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(A) The minimum sampling time for each run shall be 1 hour 

in which either an integrated sample or a minimum of four grab 

samples shall be taken. If grab sampling is used, then the 

samples shall be taken at approximately equal intervals in time, 

such as 15-minute intervals during the run.

(B) The mass rate of either TOC (minus methane and ethane) 

or total HAP (Ei, Eo) shall be computed using the equations and 

procedures specified in paragraphs (e)(3)(iii)(B)( 1 ) through ( 

3 ) of this section. As an alternative, the mass rate of either 

TOC (minus methane and ethane) or total HAP at the inlet of the 

control device (Ei) may be calculated using the procedures 

specified in paragraph (e)(3)(iii)(B)( 4 ) of this section.

(1) The following equations shall be used:

 

 

 

 

 

 

 

 

Where:

Cij, Coj= 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.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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Ei, Eo= Mass rate of TOC (minus methane and ethane) or total HAP 

at the inlet and outlet of the control device, respectively, dry 

basis, kilogram per hour.

Mij, Moj= Molecular weight of sample component j of the gas stream 

at the inlet and outlet of the control device, respectively, 

gram/gram-mole.

Qi, Qo= Flowrate of gas stream at the inlet and outlet of the 

control device, respectively, dry standard cubic meter per 

minute.

K2= 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.

n = Number of components in sample.

(2) When the TOC mass rate is calculated, all organic 

compounds (minus methane and ethane) measured by Method 18, 40 

CFR part 60, appendix A, or Method 25A, 40 CFR part 60, appendix 

A, or ASTM D6420–99 (2004) as specified in §63.772(a)(1)(ii), 

shall be summed using the equations in paragraph 

(e)(3)(iii)(B)(1) of this section.

(3) When the total HAP mass rate is calculated, only HAP 

chemicals listed in Table 1 of this subpart shall be summed 

using the equations in paragraph (e)(3)(iii)(B)(1) of this 

section.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(4) As an alternative to the procedures for calculating Ei

specified in paragraph (e)(3)(iii)(B)(1) of this section, the 

owner or operator may use the model GRI-GLYCalcTM, Version 3.0 or 

higher, and the procedures presented in the associated GRIGLYCalcTM Technical Reference Manual. Inputs to the model shall 

be representative of actual operating conditions of the glycol 

dehydration unit and shall be determined using the procedures 

documented in the Gas Research Institute (GRI) report entitled 

―Atmospheric Rich/Lean Method for Determining Glycol Dehydrator 

Emissions‖ (GRI–95/0368.1). When the TOC mass rate is 

calculated for glycol dehydration units using the model GRIGLYCalcTM , all organic compounds (minus methane and ethane) 

measured by Method 18, 40 CFR part 60, appendix A, or Method 

25A, 40 CFR part 60, appendix A, shall be summed. When the 

total HAP mass rate is calculated for glycol dehydration units 

using the model GRI-GLYCalcTM , only HAP chemicals listed in 

Table 1 of this subpart shall be summed.

(C) The percent reduction in TOC (minus methane and ethane) 

or total HAP shall be calculated as follows:

 

 

 

 

Where:

Rcd= Control efficiency of control device, percent.
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Ei= Mass rate of TOC (minus methane and ethane) or total HAP at 

the inlet to the control device as calculated under paragraph 

(e)(3)(iii)(B) of this section, kilograms TOC per hour or 

kilograms HAP per hour.

Eo= Mass rate of TOC (minus methane and ethane) or total HAP at 

the outlet of the control device, as calculated under paragraph 

(e)(3)(iii)(B) of this section, kilograms TOC per hour or 

kilograms HAP per hour.

(D) If the vent stream entering a boiler or process heater 

with a design capacity less than 44 megawatts is introduced with 

the combustion air or as a secondary fuel, the weight-percent 

reduction of total HAP or TOC (minus methane and ethane) across 

the device shall be determined by comparing the TOC (minus 

methane and ethane) or total HAP in all combusted vent streams 

and primary and secondary fuels with the TOC (minus methane and 

ethane) or total HAP exiting the device, respectively.

(iv) To determine compliance with the enclosed combustion 

device total HAP concentration limit specified in 

§63.771(d)(1)(i)(B), the owner or operator shall use one of the 

following methods to measure either TOC (minus methane and 

ethane) or total HAP: Method 18, 40 CFR part 60, appendix A; 

Method 25A, 40 CFR part 60, appendix A; ASTM D6420–99 (2004), as 

specified in §63.772(a)(1)(ii), or any other method or data that 

have been validated according to Method 301 of appendix A of 
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this part. The following procedures shall be used to calculate 

parts per million by volume concentration, corrected to 3 

percent oxygen:

(A) The minimum sampling time for each run shall be 1 hour, 

in which either an integrated sample or a minimum of four grab 

samples shall be taken. If grab sampling is used, then the 

samples shall be taken at approximately equal intervals in time, 

such as 15-minute intervals during the run.

(B) The TOC concentration or total HAP concentration shall 

be calculated according to paragraph (e)(3)(iv)(B)(1) or 

(e)(3)(iv)(B)(2) of this section.

(1) The TOC concentration is the sum of the concentrations 

of the individual components and shall be computed for each run 

using the following equation:

 

 

 

 

 

 

 

 

Where:

CTOC = Concentration of total organic compounds minus methane and 

ethane, dry basis, parts per million by volume.

Cji = 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.
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(2) The total HAP concentration shall be computed according 

to the equation in paragraph (e)(3)(iv)(B)(1) of this section, 

except that only HAP chemicals listed in Table 1 of this subpart 

shall be summed.

(C) The TOC concentration or total HAP concentration shall 

be corrected to 3 percent oxygen as follows:

(1) The emission rate correction factor for excess air, 

integrated sampling and analysis procedures of Method 3A or 3B, 

40 CFR part 60, appendix A, shall be used to determine the 

oxygen concentration. The samples shall be taken during the 

same time that the samples are taken for determining TOC 

concentration or total HAP concentration.

(2) The TOC or HAP concentration shall be corrected for 

percent oxygen by using the following equation:

 

 

 

 

Where:

Cc= TOC concentration or total HAP concentration corrected to 3 

percent oxygen, dry basis, parts per million by volume.

Cm= TOC concentration or total HAP concentration, dry basis, 

parts per million by volume.

%O2d= Concentration of oxygen, dry basis, percent by volume.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(v) To determine compliance with the BTEX emission limit 

specified in §63.771(f)(1) the owner or operator shall use one 

of the following methods: Method 18, 40 CFR part 60, appendix A; 

ASTM D6420–99 (2004), as specified in §63.772(a)(1)(ii); or any 

other method or data that have been validated according to the 

applicable procedures in Method 301, 40 CFR part 63, appendix A. 

The following procedures shall be used to calculate BTEX 

emissions:

(A) The minimum sampling time for each run shall be 1 hour 

in which either an integrated sample or a minimum of four grab 

samples shall be taken. If grab sampling is used, then the 

samples shall be taken at approximately equal intervals in time, 

such as 15-minute intervals during the run.

(B) The mass rate of BTEX (Eo) shall be computed using the 

equations and procedures specified in paragraphs (e)(3)(v)(B)(1) 

and (2) of this section. 

(1) The following equation shall be used:

 

 

 

 

Where:

Eo= Mass rate of BTEX at the outlet of the control device, dry 

basis, kilogram per hour.
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Coj= Concentration of sample component j of the gas stream at the 

outlet of the control device, dry basis, parts per million by 

volume.

Moj= Molecular weight of sample component j of the gas stream at 

the outlet of the control device, gram/gram-mole.

Qo= Flowrate of gas stream at the outlet of the control device, 

dry standard cubic meter per minute.

K2= 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.

n = Number of components in sample.

(2) When the BTEX mass rate is calculated, only BTEX 

compounds measured by Method 18, 40 CFR part 60, appendix A, or 

ASTM D6420–99 (2004) as specified in §63.772(a)(1)(ii), shall be 

summed using the equations in paragraph (e)(3)(v)(B)(1) of this 

section.

(vi) The owner or operator shall conduct performance tests 

according to the schedule specified in paragraphs (e)(3)(vi)(A) 

and (B) of this section.

(A) An initial performance test shall be conducted within 

180 days after the compliance date that is specified for each 

affected source in §63.760(f)(7) through (8), except that the 

initial performance test for existing combustion control devices 
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at existing major sources shall be conducted no later than 3 

years after the date of publication of the final rule in the 

Federal Register. If the owner or operator of an existing 

combustion control device at an existing major source chooses to 

replace such device with a control device whose model is tested

under §63.772(h), then the newly installed device shall comply 

with all provisions of this subpart no later than 3 years after 

the date of publication of the final rule in the Federal 

Register. The performance test results shall be submitted in 

the Notification of Compliance Status Report as required in 

§63.775(d)(1)(ii).

(B) Periodic performance tests shall be conducted for all 

control devices required to conduct initial performance tests 

except as specified in paragraphs (e)(3)(vi)(B)(1) and (2) of 

this section. The first periodic performance test shall be 

conducted no later than 60 months after the initial performance 

test required in paragraph (e)(3)(vi)(A) of this section. 

Subsequent periodic performance tests shall be conducted at 

intervals no longer than 60 months following the previous

periodic performance test or whenever a source desires to 

establish a new operating limit. The periodic performance test 

results must be submitted in the next Periodic Report as 

specified in §63.775(e)(2)(xi). Combustion control devices 

meeting the criteria in either paragraph (e)(3)(vi)(B)(1) or (2) 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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of this section are not required to conduct periodic performance 

tests.

(1) A control device whose model is tested under, and meets 

the criteria of, §63.772(h), or

(2) A combustion control device tested under §63.772(e) 

that meets the outlet TOC or HAP performance level specified in

§63.771(d)(1)(i)(B) and that establishes a correlation between

firebox or combustion chamber temperature and the TOC or HAP 

performance level.

(4) For a condenser design analysis conducted to meet the 

requirements of §63.771(d)(1) or , (e)(3)(ii), or (f)(1), the 

owner or operator shall meet the requirements specified in 

paragraphs (e)(4)(i) and (e)(4)(ii) of this section. 

Documentation of the design analysis shall be submitted as a 

part of the Notification of Compliance Status Report as required 

in §63.775(d)(1)(i).

(i) The condenser design analysis shall include an analysis 

of include analysis of the vent stream characteristics and 

control device operating parameters for the applicable control

device as specified in paragraphs (e)(4)(i)(A) through (F) of 

this section.

(A) For a thermal vapor incinerator, the design analysis 

shall include the vent stream composition, constituent 

concentrations, and flowrate and shall establish the design 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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minimum and average temperatures in the combustion zone and the 

combustion zone residence time.

(B) For a catalytic vapor incinerator, the design analysis 

shall include the vent stream composition, constituent 

concentrations, and flowrate and shall establish the design 

minimum and average temperatures across the catalyst bed inlet 

and outlet, and the design service life of the catalyst.

(C) For a boiler or process heater, the design analysis 

shall include the vent stream composition, constituent 

concentrations, and flowrate; shall establish the design minimum 

and average flame zone temperatures and combustion zone 

residence time; and shall describe the method and location where 

the vent stream is introduced into the flame zone.

(D) For a condenser, the design analysis shall include the 

vent stream composition, constituent concentrations, flowrate, 

relative humidity, and temperature, and shall establish the 

design outlet organic compound 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. As an alternative to the condenser 

design analysis, an owner or operator may elect to use the 

procedures specified in paragraph (e)(5) of this section.

(E) For a regenerable carbon adsorption system, the design 

analysis shall include the vent stream composition, constituent 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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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 regeneration time, and design 

service life of the carbon.

(F) For a nonregenerable carbon adsorption system, such as 

a carbon canister, the design analysis shall include the vent 

stream composition, constituent concentrations, flowrate, 

relative humidity, and temperature, 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.

(ii) If the owner or operator and the Administrator do not 

agree on a demonstration of control device performance using a 

design analysis then the disagreement shall be resolved using 

the results of a performance test performed by the owner or 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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operator in accordance with the requirements of paragraph (e)(3) 

of this section. The Administrator may choose to have an 

authorized representative observe the performance test.

(5) As an alternative to the procedures in paragraphs

(e)(3) and (e)(4)(i)(D) of this section, an owner or operator 

may elect to use the procedures documented in the GRI report 

entitled, ―Atmospheric Rich/Lean Method for Determining Glycol 

Dehydrator Emissions‖ (GRI–95/0368.1) as inputs for the model 

GRI-GLYCalcTM , Version 3.0 or higher, to determine generate a

condenser performance curve.

(f) Compliance demonstration for control device performance 

requirements. This paragraph applies to the demonstration of 

compliance with the control device performance requirements

specified in §63.771(d)(1)(i), and (e)(3) and (f)(1). 

Compliance shall be demonstrated using the requirements in 

paragraphs (f)(1) through (3) of this section. As an 

alternative, an owner or operator that installs a condenser as 

the control device to achieve the requirements specified in 

§63.771(d)(1)(ii), or (e)(3) or (f)(1) may demonstrate 

compliance according to paragraph (g) of this section. An owner 

or operator may switch between compliance with paragraph (f) of 

this section and compliance with paragraph (g) of this section 

only after at least 1 year of operation in compliance with the 

selected approach. Notification of such a change in the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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compliance method shall be reported in the next Periodic Report, 

as required in §63.775(e), following the change.

(1) The owner or operator shall establish a site specific 

maximum or minimum monitoring parameter value (as appropriate) 

according to the requirements of §63.773(d)(5)(i).

(2) The owner or operator shall calculate the daily average 

of the applicable monitored parameter in accordance with 

§63.773(d)(4) except that the inlet gas flow rate to the control 

device shall not be averaged.

(3) Compliance with the operating parameter limit is 

achieved when the daily average of the monitoring parameter 

value calculated under paragraph (f)(2) of this section is 

either equal to or greater than the minimum or equal to or less 

than the maximum monitoring value established under paragraph 

(f)(1) of this section. For inlet gas flow rate, compliance 

with the operating parameter limit is achieved when the value is 

equal to or less than the value established under §63.772(h).

(4) 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), the CMS required in 

§63.773(d) must be operated at all times the affected source is 

operating. A monitoring system malfunction is any sudden, 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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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. Monitoring system repairs are required to be 

completed in response to monitoring system malfunctions and to 

return the monitoring system to operation as expeditiously as 

practicable.

(5) Data recorded during monitoring system malfunctions, 

repairs associated with monitoring system malfunctions, or 

required monitoring system quality assurance or control 

activities may not be used in calculations used to report 

emissions or operating levels. All the data collected during 

all other required data collection periods must be used in 

assessing the operation of the control device and associated 

control system. 

(6) 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 zero and span adjustments), failure to 

collect required data is a deviation of the monitoring 

requirements.

(g) Compliance demonstration with percent reduction or 

emission limit performance requirements—condensers. This 
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paragraph applies to the demonstration of compliance with the 

performance requirements specified in §63.771(d)(1)(ii), or 

(e)(3) or (f)(1) for condensers. Compliance shall be 

demonstrated using the procedures in paragraphs (g)(1) through 

(3) of this section.

(1) The owner or operator shall establish a site-specific 

condenser performance curve according to §63.773(d)(5)(ii). For 

sources required to meet the BTEX limit in accordance with 

§63.771(e) or (f)(1) the owner or operator shall identify the

minimum percent reduction necessary to meet the BTEX limit.

(2) Compliance with the percent reduction requirements in 

§63.771(d)(1)(ii), or (e)(3) or (f)(1) shall be demonstrated by 

the procedures in paragraphs (g)(2)(i) through (iii) of this 

section.

(i) The owner or operator must calculate the daily average 

condenser outlet temperature in accordance with §63.773(d)(4).

(ii) The owner or operator shall determine the condenser 

efficiency for the current operating day using the daily average 

condenser outlet temperature calculated under paragraph 

(g)(2)(i) of this section and the condenser performance curve 

established under paragraph (g)(1) of this section.

(iii) Except as provided in paragraphs (g)(2)(iii)(A) and 

(B) of this section, at the end of each operating day, the owner 

or operator shall calculate the 365-day average HAP, or BTEX,
Proposed Subpart HH Redline/Strikeout July 28, 2011

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emission reduction, as appropriate, from the condenser 

efficiencies as determined in paragraph (g)(2)(ii) of this 

section for the preceding 365 operating days. If the owner or 

operator uses a combination of process modifications and a 

condenser in accordance with the requirements of §63.771(e), the 

365-day average HAP, or BTEX, emission reduction shall be 

calculated using the emission reduction achieved through process 

modifications and the condenser efficiency as determined in 

paragraph (g)(2)(ii) of this section, both for the previous 365

operating days.

(A) After the compliance dates specified in §63.760(f), an 

owner or operator with less than 120 days of data for 

determining average HAP, or BTEX, emission reduction, as 

appropriate, shall calculate the average HAP, or BTEX emission 

reduction, as appropriate, for the first 120 days of operation 

after the compliance dates. For sources required to meet the 

overall 95.0 percent reduction requirement, cCompliance with the 

performance requirements is achieved if the 120-day average HAP 

emission reduction is equal to or greater than 90.0 percent. 

For sources required to meet the BTEX limit under

§63.765(b)(1)(iii), compliance is achieved if the average BTEX 

emission reduction is at least 95.0 percent of the required 365-

day value identified under paragraph (g)(1) of this section 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(i.e, at least 76.0 percent if the 365-day design value is 80.0 

percent).

(B) After 120 days and no more than 364 days of operation 

after the compliance dates specified in §63.760(f), the owner or 

operator shall calculate the average HAP emission reduction as 

the HAP emission reduction averaged over the number of days 

between the current day and the applicable compliance date. For 

sources required to meet the overall 95.0 percent reduction 

requirement, cCompliance with the performance requirements is 

achieved if the average HAP emission reduction is equal to or 

greater than 90.0 percent. For sources required to meet the 

BTEX limit under §63.765(b)(1)(iii), compliance is achieved if 

the average BTEX emission reduction is at least 95.0 percent of

the required 365-day value identified under paragraph (g)(1) of 

this section (i.e, at least 76.0 percent if the 365-day design 

value is 80.0 percent).

(3) If the owner or operator has data for 365 days or more 

of operation, compliance is achieved with based on the 

applicable criteria in paragraphs (g)(3)(i) or (ii) of this 

section.

(i) For sources meeting the HAP emission limitation 

reduction specified in §63.771(d)(1)(ii) or (e)(3) if the 

average HAP emission reduction calculated in paragraph 
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(g)(2)(iii) of this section is equal to or greater than 95.0 

percent.

(ii) For sources required to meet the BTEX limit under

§63.771(e)(3) or (f)(1), compliance is achieved if the average

BTEX emission reduction calculated in paragraph (g)(2)(iii) of 

this section is equal to or greater than the minimum percent 

reduction identified in paragraph (g)(1) of this section.

(h) 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 manufacturer. 

The manufacturer shall demonstrate that a specific model of 

control device achieves the performance requirements in (h)(7) 

of this section by conducting a performance test as specified in 

paragraphs (h)(2) through (6) of this section. 

(2) Performance testing shall consist of three one-hour (or 

longer) test runs for each of the four following firing rate 

settings making a total of 12 test runs per test. Propene 

(propylene) gas shall be used for the testing fuel. All fuel 

analyses shall be performed by an independent third-party 

laboratory (not affiliated with the control device manufacturer 

or fuel supplier).

(i) 90 - 100 percent of maximum design rate (fixed rate).
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(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 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 maximum 

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 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 for 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 the firing rate to 100 percent of the maximum 

design rate. Hold at 30 percent for 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) All models employing multiple enclosures shall be 

tested simultaneously and with all burners operational. Results 

shall be reported for the each enclosure individually and for 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 88 of ???

the average of the emissions from all interconnected combustion 

enclosures/chambers. Control device operating data shall be 

collected continuously throughout the performance test using an 

electronic Data Acquisition System and strip chart. Data shall 

be submitted with the test report in accordance with paragraph 

(8)(iii) of this section.

(4) Inlet testing shall be conducted as specified in 

paragraphs (h)(4)(i) through (iii) of this section.

(i) The fuel flow metering system shall be located in 

accordance with Method 2A, 40 CFR part 60, appendix A-1, (or 

other approved procedure) to measure fuel flow rate at the 

control device inlet location. The fitting for filling fuel 

sample containers shall be located a minimum of 8 pipe diameters 

upstream of any inlet fuel flow monitoring meter.

(ii) Inlet flow rate shall be determined using Method 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 THC 

test.

(iii) Inlet fuel sampling shall be conducted in accordance 

with the criteria in paragraphs (h)(4)(iii)(A) and (B) of this 

section.

(A) At the inlet fuel sampling location, securely connect a 

Silonite-coated stainless steel evacuated canister fitted with a 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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flow controller sufficient to fill the canister over a 1 hour 

period. Filling shall be conducted as specified in the 

following: 

(1) Open the canister sampling valve at the beginning of 

the total hydrocarbon (THC) test, and close the canister at the 

end of the THC test.

(2) Fill one canister for each THC test run.

(3) Label the canisters individually and record on a chain 

of custody form.

(B) Each fuel sample shall be analyzed using the following 

methods. The results shall be included in the test report.

(1) Hydrocarbon compounds containing between one and five 

atoms of carbon plus benzene using ASTM D1945-03.

(2) Hydrogen (H2), carbon monoxide (CO), carbon dioxide 

(CO2), nitrogen (N2), oxygen (O2) using ASTM D1945-03.

(3) Carbonyl sulfide, carbon disulfide plus mercaptans 

using ASTM D5504.

(4) Higher heating value using ASTM D3588-98 or ASTM D4891-

89.

(5) Outlet testing shall be conducted in accordance with 

the criteria in paragraphs (h)(5)(i) through (v) of this 

section.

(i) Sampling and flowrate measured in accordance with the 

following:
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(A) The outlet sampling location shall be a minimum of 4 

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 shall be used. 

(B) Flow rate shall be measured using Method 1, 40 CFR part 

60, Appendix 1, for determining flow measurement traverse point 

location; and Method 2, 40 CFR part 60, Appendix 1, shall be 

used to measure 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 shall be used to obtain an accurate flow 

profile.

(ii) Molecular weight shall be determined as specified in 

paragraphs (h)(4)(iii)(B), (h)(5)(ii)(A) and (h)(5)(ii)(B) of 

this section.

(A) An integrated bag sample shall be collected during the 

Method 4, 40 CFR part 60, Appendix A, moisture test. Analyze the 

bag sample using a gas chromatograph-thermal conductivity 

detector (GC-TCD) analysis meeting the following criteria:

(1) Collect the integrated sample throughout the entire 

test, and collect representative volumes from each traverse 

location.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(2) The sampling line shall be purged with stack gas before 

opening the valve and beginning to fill the bag.

(3) The bag contents shall be kneaded or otherwise 

vigorously mixed prior to the GC analysis.

(4) The GC-TCD calibration procedure in Method 3C, 40 CFR 

part 60, Appendix A, shall 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, the initial calibration using at least 

three concentration levels shall be repeated.

(B) Report the molecular weight of: O2, CO2, methane (CH4), 

and N2 and include in the test report submitted under §63.775(d)

(iii) Moisture shall be determined using Method 4, 40 CFR part 

60, Appendix A. Traverse both ports with the Method 4, 40 CFR 

part 60, Appendix A, sampling train during each test run. 

Ambient air shall not be introduced into the Method 3C, 40 CFR 

part 60, Appendix A, integrated bag sample during the port 

change.

(iii) Carbon monoxide shall be determined using Method 10, 

40 CFR part 60, Appendix A. The test shall be run at the same 

time and with the sample points used for the EPA Method 25A, 40 
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CFR part 60, Appendix A, testing. An instrument range of 0-10 

per million by volume-dry (ppmvd) shall be used.

(iv) Visible emissions shall be determined using Method 22, 

40 CFR part 60, Appendix A. The test shall 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.

(6) Total hydrocarbons (THC) shall be determined as 

specified by the following criteria:

(i) Conduct THC sampling using Method 25A, 40 CFR part 60, 

Appendix A, except the option for locating the probe in the 

center 10 percent of the stack shall not be 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 shall consist of three Method 25A, 40 CFR 

part 60, Appendix A, 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 will be propane in air and be 

certified through EPA Protocol 1 – ―EPA Traceability Protocol 

for Assay and Certification of Gaseous Calibration Standards,‖ 
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September 1997, as amended August 25, 1999, EPA–600/R–97/121 (or 

more recent if updated since 1999).

(v) THC measurements shall be reported in terms of 

ppmvw as propane.

(vi) THC results shall be corrected to 3 percent CO2, as 

measured by Method 3C, 40 CFR part 60, Appendix A.

(vii) Subtraction of methane/ethane from the THC data is 

not allowed in determining results.

(7) Performance test criteria:

(i) The control device model tested must meet the criteria 

in paragraphs (h)(7)(i)(A) through (C) of this section:

(A) Method 22, 40 CFR part 60, Appendix A, results under

paragraph (h)(5)(v) of this section with no indication of 

visible emissions, and

(B) Average Method 25A, 40 CFR part 60, Appendix A, 

results under paragraph (h)(6) of this section equal to or less 

than 10.0 ppmvw THC as propane corrected to 3.0 percent CO2, and 

(C) Average CO emissions determined under paragraph 

(h)(5)(iv) of this section equal to or less than 10 parts ppmvd, 

corrected to 3.0 percent CO2.

(ii) The manufacturer shall determine a maximum inlet gas 

flow rate which shall not be exceeded for each control device 

model to achieve the criteria in paragraph (h)(7)(i) of this 

section.
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(iii) A control device meeting the criteria in paragraph 

(h)(7)(i)(A) through (C) of this section will have demonstrated 

a destruction efficiency of 98.0 percent for HAP regulated under 

this subpart.

(8) The owner or operator of a combustion control device 

model tested under this section shall submit the information 

listed in paragraphs (h)(8)(i) through (iii) of this section in 

the test report required under §63.775(d)(1)(iii).

(i) Full schematic of the control device and dimensions of 

the device components.

(ii) Design net heating value (minimum and maximum) of the 

device.

(iii) Test fuel gas flow range (in both mass and volume). 

Include the minimum and maximum allowable inlet gas flow rate.

(iv) Air/stream injection/assist ranges, if used.

(v) The test parameter ranges listed in paragraphs 

(h)(8)(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.
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(F) Excess combustion air range.

(G) Flame arrestor(s).

(H) Burner manifold pressure.

(I) Pilot flame sensor.

(J) Pilot flame design fuel and 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 shall include all calibration quality 

assurance/quality control data, calibration gas values, gas 

cylinder certification, and strip charts annotated with test 

times and calibration values. 

(i) Compliance demonstration for combustion control devices 

- manufacturers’ performance test. This paragraph applies to the 

demonstration of compliance for a combustion control device 

tested under the provisions in paragraph (h) of this section. 

Owners or operators shall demonstrate that a control device 

achieves the performance requirements of §63.771(d)(1), 

(e)(3)(ii) or (f)(1), by installing a device tested under 

paragraph (h) of this section and complying with the following 

criteria: 
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(1) The inlet gas flow rate shall meet the range specified 

by the manufacturer. Flow rate shall be measured as specified in 

§63.773(d)(3)(i)(H)(1).

(2) A pilot flame shall be present at all times of 

operation. The pilot flame shall be monitored in accordance with 

§63.773(d)(3)(i)(H)(2).

(3) Devices shall be operated with no visible emissions, 

except for periods not to exceed a total of 5 minutes during any 

2 consecutive hours. A visible emissions test using Method 22, 

40 CFR part 60, Appendix A, shall be performed monthly. The 

observation period shall be 2 hours and shall be used according 

to Method 22. 

(4) Compliance with the operating parameter limit is 

achieved when the following criteria are met:

(i) The inlet gas flow rate monitored under paragraph 

(i)(1) of this section is equal to or below the maximum 

established by the manufacturer; and

(ii) The pilot flame is present at all times; and

(iii) During the visible emissions test performed under 

paragraph (i)(3) of this section the duration of visible 

emissions does not exceed a total of 5 minutes during the 

observation period. Devices failing the visible emissions test 

shall follow the requirements in paragraphs (i)(4)(iii)(A) and 

(B) of this section.
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(A) Following the first failure, the fuel nozzle(s) 

and burner tubes shall be replaced. 

(B) If, following replacement of the fuel nozzle(s) and 

burner tubes as specified in paragraph (i)(4)(iii)(A), the 

visible emissions test is not passed in the next scheduled test, 

either a performance test shall be performed under paragraph (e) 

of this section, or the device shall be replaced with another 

control device whose model was tested, and meets, the 

requirements in paragraph (h) of this section.

§ 63.773 Inspection and monitoring requirements.

(a) This section applies to an owner or operator using air 

emission controls in accordance with the requirements of 

§§63.765 and 63.766.

(b) The owner or operator of a control device whose model 

was tested under §63.772(h) shall develop an inspection and 

maintenance plan for each control device. At a minimum, the 

plan shall contain the control device manufacturer’s 

recommendations for ensuring proper operation of the device. 

Semi-annual inspections shall be conducted for each control 

device with maintenance and replacement of control device

components made in accordance with the plan.[Reserved]

(c) Cover and closed-vent system inspection and monitoring 

requirements. (1) For each closed-vent system or cover required 

to comply with this section, the owner or operator shall comply 
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with the requirements of paragraphs (c) (2) through (7) of this 

section.

(2) Except as provided in paragraphs (c)(5) and (6) of this 

section, each closed-vent system shall be inspected according to 

the procedures and schedule specified in paragraphs (c)(2)(i) 

and (ii) of this section, each cover shall be inspected 

according to the procedures and schedule specified in paragraph 

(c)(2)(iii) of this section, and each bypass device shall be 

inspected according to the procedures of paragraph (c)(2)(iv) of 

this section.

(i) For each closed-vent system joints, seams, or other 

connections that are permanently or semi-permanently sealed 

(e.g., a welded joint between two sections of hard piping or a 

bolted and gasketed ducting flange), the owner or operator 

shall:

(A) Conduct an initial inspection according to the 

procedures specified in §63.772(c) to demonstrate that the 

closed-vent system operates with no detectable emissions. 

Inspection results shall be submitted with the Notification of 

Compliance Status Report as specified in §63.775(d)(1) or (2).

(B) 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; or broken or missing caps or other closure devices. 
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The owner or operator shall monitor a component or connection 

using the procedures in §63.772(c) to demonstrate that it 

operates with no detectable emissions following any time the 

component is repaired or replaced or the connection is unsealed. 

Inspection results shall be submitted in the Periodic Report as 

specified in §63.775(e)(2)(iii).

(ii) For closed-vent system components other than those 

specified in paragraph (c)(2)(i) of this section, the owner or 

operator shall:

(A) Conduct an initial inspection according to the 

procedures specified in §63.772(c) to demonstrate that the 

closed-vent system operates with no detectable emissions. 

Inspection results shall be submitted with the Notification of 

Compliance Status Report as specified in §63.775(d)(1) or (2).

(B) Conduct annual inspections according to the procedures 

specified in §63.772(c) to demonstrate that the components or 

connections operate with no detectable emissions. Inspection 

results shall be submitted in the Periodic Report as specified 

in §63.775(e)(2)(iii).

(C) 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; or broken or missing caps or other closure devices. 
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Inspection results shall be submitted in the Periodic Report as 

specified in §63.775(e)(2)(iii).

(iii) For each cover, the owner or operator shall:

(A) 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 

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. 

In the case where the storage vessel is buried partially or 

entirely underground, inspection is required only for 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, access hatches, gauge wells, etc.) and 

can be opened to the atmosphere.

(B) The inspections specified in paragraph (c)(2)(iii)(A) 

of this section shall be conducted initially, following the 

installation of the cover. Inspection results shall be 

submitted with the Notification of Compliance Status Report as 

specified in §63.775(d)(12). Thereafter, the owner or operator 

shall perform the inspection at least once every calendar year, 

except as provided in paragraphs (c)(5) and (6) of this section. 

Annual inspection results shall be submitted in the Periodic 

Report as specified in §63.775(e)(2)(iii).
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(iv) For each bypass device, except as provided for in 

§63.771(c)(3)(ii), the owner or operator shall either:

(A) At the inlet to the bypass device that could divert the 

steam away from the control device to the atmosphere, set the 

flow indicator to take a reading at least once every 15 minutes; 

or

(B) 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 bypass 

device.

(3) In the event that a leak or defect is detected, the 

owner or operator shall repair the leak or defect as soon as 

practicable, except as provided in paragraph (c)(4) of this 

section.

(i) A first attempt at repair shall be made no later than 5 

calendar days after the leak is detected.

(ii) Repair shall be completed no later than 15 calendar 

days after the leak is detected.

(4) 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, as defined 
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in §63.761, or if the owner or operator determines that 

emissions resulting from immediate repair would be greater than 

the fugitive emissions likely to result from delay of repair. 

Repair of such equipment shall be complete by the end of the 

next shutdown.

(5) Any parts of the closed-vent system or cover that are 

designated, as described in paragraphs (c)(5) (i) and (ii) of 

this section, as unsafe to inspect are exempt from the 

inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) 

of this section if:

(i) The owner or operator determines that the equipment is 

unsafe to inspect because inspecting personnel would be exposed 

to an imminent or potential danger as a consequence of complying 

with paragraphs (c)(2)(i), (ii), or (iii) of this section; and

(ii) The owner or operator has a written plan that requires 

inspection of the equipment as frequently as practicable during 

safe-to-inspect times.

(6) Any parts of the closed-vent system or cover that are 

designated, as described in paragraphs (c)(6) (i) and (ii) of 

this section, as difficult to inspect are exempt from the 

inspection requirements of paragraphs (c)(2)(i), (ii), and (iii) 

of this section if:
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(i) The owner or operator determines that the equipment 

cannot be inspected without elevating the inspecting personnel 

more than 2 meters above a support surface; and

(ii) The owner or operator has a written plan that requires 

inspection of the equipment at least once every 5 years.

(7) Records shall be maintained as specified in 

§63.774(b)(5) through (8).

(d) Control device monitoring requirements. (1) For each 

control device, except as provided for in paragraph (d)(2) of 

this section, the owner or operator shall install and operate a 

continuous parameter monitoring system in accordance with the 

requirements of paragraphs (d)(3) through (9) of this section. 

Owners or operators that install and operate a flare in 

accordance with §63.771(d)(1)(iii) or (f)(1)(iii) are exempt 

from the requirements of paragraphs (d)(4) and (5) of this 

section. The continuous monitoring system shall be designed and 

operated so that a determination can be made on whether the 

control device is achieving the applicable performance 

requirements of §63.771(d), or (e)(3) or (f)(1). The Each 

continuous parameter monitoring system shall meet the following 

specifications and requirements:

(i) Each continuous parameter monitoring system shall 

measure data values at least once every hour and record either:

(A) Each measured data value; or
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(B) 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 than 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.

(ii) A site-specific monitoring plan must be prepared that 

addresses the monitoring system design, data collection, and the

quality assurance and quality control elements outlined in 

paragraph (d) of this section and in §63.8(d). Each The CPMS 

monitoring system must be installed, calibrated, operated, and 

maintained in accordance with the manufacturer's specifications 

or other written procedures that provide reasonable assurance 

that the monitoring equipment is operating properly.the 

procedures in your approved site-specific monitoring plan. 

Using the process described in §63.8(f)(4), you may request 

approval of monitoring system quality assurance and quality 

control procedures alternative to those specified in paragraphs 

(d)(1)(ii)(A) through (E) of this section in your site-specific 

monitoring plan.

(A) The performance criteria and design specifications for 

the monitoring system equipment, including the sample interface, 

detector signal analyzer, and data acquisition and calculations;
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(B) Sampling interface (e.g., thermocouple) location such 

that the monitoring system will provide representative 

measurements; 

(C) Equipment performance checks, system accuracy audits, 

or other audit procedures;

(D) Ongoing operation and maintenance procedures in 

accordance with provisions in §63.8(c)(1) and (c)(3); and

(E) Ongoing reporting and recordkeeping procedures in 

accordance with provisions in §63.10(c), (e)(1), and (e)(2)(i).

(iii) The owner or operator must conduct the CPMS equipment 

performance checks, system accuracy audits, or other audit 

procedures specified in the site-specific monitoring plan at 

least once every 12 months.

(iv) The owner or operator must conduct a performance 

evaluation of each CPMS in accordance with the site-specific 

monitoring plan.

(2) An owner or operator is exempt from the monitoring 

requirements specified in paragraphs (d)(3) through (9) of this 

section for the following types of control devices:

(i) Except for control devices for small glycol dehydration 

units, Aa boiler or process heater in which all vent streams are 

introduced with the primary fuel or is used as the primary fuel; 

or
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(ii) Except for control devices for small glycol 

dehydration units, aA boiler or process heater with a design 

heat input capacity equal to or greater than 44 megawatts.

(3) The owner or operator shall install, calibrate, 

operate, and maintain a device equipped with a continuous 

recorder to measure the values of operating parameters 

appropriate for the control device as specified in either 

paragraph (d)(3)(i), (d)(3)(ii), or (d)(3)(iii) of this section.

(i) A continuous monitoring system that measures the 

following operating parameters as applicable:

(A) For a thermal vapor incinerator that demonstrates 

during the performance test conducted under §63.772(e) that 

combustion zone temperature is an accurate indicator of 

performance, a temperature monitoring device equipped with a 

continuous recorder. The monitoring device shall have a minimum 

accuracy of ±12 percent of the temperature being monitored in °C 

,or ±2.5 °C, whichever value is greater. The temperature sensor 

shall be installed at a location in the combustion chamber 

downstreamrepresentative of the combustion zone temperature.

(B) For a catalytic vapor incinerator, a temperature 

monitoring device equipped with a continuous recorder. The 

device shall be capable of monitoring temperature at two 

locations and have a minimum accuracy of ±12 percent of the 

temperature being monitored in °C, or ±2.5 °C, whichever value 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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is greater. One temperature sensor shall be installed in the 

vent stream at the nearest feasible point to the catalyst bed 

inlet and a second temperature sensor shall be installed in the 

vent stream at the nearest feasible point to the catalyst bed 

outlet.

(C) For a flare, a heat sensing monitoring device equipped 

with a continuous recorder that indicates the continuous 

ignition of the pilot flame.

(D) For a boiler or process heater with a design heat input 

capacity of less than 44 megawatts, a temperature monitoring 

device equipped with a continuous recorder. The temperature 

monitoring device shall have a minimum accuracy of ±12 percent

of the temperature being monitored in °C, or ±2.5 °C, whichever 

value is greater. The temperature sensor shall be installed at 

a location in the combustion chamber downstreamrepresentative 

of the combustion zone temperature.

(E) For a condenser, a temperature monitoring device 

equipped with a continuous recorder. The temperature monitoring 

device shall have a minimum accuracy of ±2 1 percent of the 

temperature being monitored in °C, or ±2.5 8 °C, whichever value 

is greater. The temperature sensor shall be installed at a 

location in the exhaust vent stream from the condenser.

(F) For a regenerative-type carbon adsorption system:
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(1) A continuous parameter monitoring system to 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. The mechanical connections for leakage must be checked 

at least every month, and a visual inspection must be performed 

at least every 3 months of all components of the flow CPMS for 

physical and operational integrity and all electrical 

connections for oxidation and galvanic corrosion if your flow 

CPMS is not equipped with a redundant flow sensorThe integrating 

regenerating stream flow monitoring device must have an accuracy 

of ±10 percent; and

(2) A continuous parameter monitoring system to measure and 

record the average carbon bed temperature for the duration of 

the carbon bed steaming cycle and to measure the actual carbon 

bed temperature after regeneration and within 15 minutes of 

completing the cooling cycle. The temperature monitoring device 

shall have a minimum accuracy of ±21 percent of the temperature 

being monitored in °C, or ±2.5 °C, whichever value is greater.

(G) For a nonregenerative-type carbon adsorption system, 

the owner or operator shall monitor the design carbon 

replacement interval established using a performance test 

performed in accordance with §63.772(e)(3) or a design analysis 
Proposed Subpart HH Redline/Strikeout July 28, 2011

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in accordance with §63.772(e)(4)(i)(F) and shall be based on the 

total carbon working capacity of the control device and source 

operating schedule.

(H) For a control device model whose model is tested under 

§63.772(h):

(1) A continuous monitoring system that measures gas flow 

rate at the inlet to the control device. The monitoring 

instrument shall have an accuracy of plus or minus 2 percent or

better.

(2) A heat sensing monitoring device equipped with a 

continuous recorder that indicates the continuous ignition of 

the pilot flame.

(ii) A continuous monitoring system that measures the 

concentration level of organic compounds 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 

appendix B of 40 CFR part 60 and must be installed, calibrated, 

and maintained according to the manufacturer's specifications.

(iii) A continuous monitoring system that measures 

alternative operating parameters other than those specified in 

paragraph (d)(3)(i) or (d)(3)(ii) of this section upon approval 

of the Administrator as specified in §63.8(f)(1) through (5).
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(4) Using the data recorded by the monitoring system, 

except for inlet gas flow rate, the owner or operator must 

calculate the daily average value for each monitored operating 

parameter for each operating day. If the HAP emissions unit 

operation is continuous, the operating day is a 24-hour period. 

If the HAP 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 operating hours in an operating 

day to compute the daily average.

(5) For each operating parameter monitor installed in 

accordance with the requirements of paragraph (d)(3) of this 

section, the owner or operator shall comply with paragraph 

(d)(5)(i) of this section for all control devices, and when 

condensers are installed, the owner or operator shall also 

comply with paragraph (d)(5)(ii) of this section.

(i) The owner or operator shall establish a minimum 

operating parameter value or a maximum operating parameter 

value, as appropriate for the control device, to define the 

conditions at which the control device must be operated to 

continuously achieve the applicable performance requirements of 

§63.771(d)(1), or §63.771(e)(3)(ii) or (f)(1). Each minimum or 

maximum operating parameter value shall be established as 

follows:
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(A) If the owner or operator conducts performance tests in 

accordance with the requirements of §63.772(e)(3) to demonstrate 

that the control device achieves the applicable performance 

requirements specified in §63.771(d)(1) , or §63.771(e)(3)(ii)

or (f)(1), then the minimum operating parameter value or the 

maximum operating parameter value shall be established based on 

values measured during the performance test and supplemented, as 

necessary, by a control device condenser design analysis or 

control device manufacturer recommendations or a combination of 

both.

(B) If the owner or operator uses a condenser control 

device design analysis in accordance with the requirements of 

§63.772(e)(4) to demonstrate that the control device achieves 

the applicable performance requirements specified in 

§63.771(d)(1) or, (e)(3)(ii) or (f)(1), then the minimum 

operating parameter value or the maximum operating parameter 

value shall be established based on the control devicecondenser

design analysis and may be supplemented by the control 

devicecondenser manufacturer's recommendations.

(C) If the owner or operator operates a control device 

where the performance test requirement was met under §63.772(h)

to demonstrate that the control device achieves the applicable 

performance requirements specified in §63.771(d)(1), (e)(3)(ii)

or (f)(1), then the maximum inlet gas flow rate shall be 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 112 of ???

established based on the performance test and supplemented, as 

necessary, by the manufacturer recommendations.

(ii) The owner or operator shall establish a condenser 

performance curve showing the relationship between condenser 

outlet temperature and condenser control efficiency. The curve 

shall be established as follows:

(A) If the owner or operator conducts a performance test in 

accordance with the requirements of §63.772(e)(3) to demonstrate 

that the condenser achieves the applicable performance 

requirements in §63.771(d)(1) or, (e)(3)(ii) or (f)(1), then the 

condenser performance curve shall 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.

(B) If the owner or operator uses a control device design 

analysis in accordance with the requirements of 

§63.772(e)(4)(i)(D) to demonstrate that the condenser achieves 

the applicable performance requirements specified in 

§63.771(d)(1), or (e)(3)(ii) or (f)(1), then the condenser 

performance curve shall be based on the condenser design 

analysis and may be supplemented by the control device 

manufacturer's recommendations.

(C) As an alternative to paragraphs (d)(5)(ii)(A) and (B) 

of this section, the owner or operator may elect to use the 
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procedures documented in the GRI report entitled, ―Atmospheric 

Rich/Lean Method for Determining Glycol Dehydrator Emissions‖ 

(GRI–95/0368.1) as inputs for the model GRI-GLYCalcTM , Version 

3.0 or higher, to generate a condenser performance curve.

(6) An excursion 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 

(d)(6)(i) through (d)(6)(v) of this section being met. When 

multiple operating parameters are monitored for the same control 

device and during the same operating day and more than one of 

these operating parameters meets an excursion criterion 

specified in paragraphs (d)(6)(i) through (d)(6)(v) of this 

section, then a single excursion is determined to have occurred 

for the control device for that operating day.

(i) An excursion 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 for the operating 

parameter in accordance with the requirements of paragraph 

(d)(5)(i) of this section.

(ii) For sources meeting §63.771(d)(1)(ii), aAn excursion 

occurs when the 365-day average condenser efficiency calculated 

according to the requirements specified in §63.772(g)(2)(iii) is 

less than 95.0 percent. For sources meeting §63.771(f)(1), an 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 114 of ???

excursion occurs when the 365-day average condenser efficiency 

calculated according to the requirements specified in 

§63.772(g)(2)(iii) is less than 95.0 percent of the identified 

365-day required percent reduction.

(iii) For sources meeting §63.771(d)(1)(ii), iIf an owner 

or operator has less than 365 days of data, an excursion occurs 

when the average condenser efficiency calculated according to 

the procedures specified in §63.772(g)(2)(iii)(A) or (B) is less 

than 90.0 percent. For sources meeting §63.771(d)(1)(ii), an 

excursion occurs when the 365-day average condenser efficiency 

calculated according to the requirements specified in 

§63.772(g)(2)(iii) is less than the identified 365-day required 

percent reduction.

(iv) An excursion occurs when the monitoring data are not 

available for at least 75 percent of the operating hours in a 

day.

(v) If the closed-vent system contains one or more bypass 

devices that could be used to divert all or a portion of the 

gases, vapors, or fumes from entering the control device, an 

excursion occurs when:

(A) For each bypass line subject to §63.771(c)(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.
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(B) For each bypass line subject to §63.771(c)(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 

lock has been checked out, or the car-seal has broken.

(vi) For a control device whose model is tested under 

§63.772(h) an excursion occurs when:

(A) The inlet gas flow rate exceeds the maximum established 

during the test conducted under §63.772(h).

(B) Failure of the monthly visible emissions test conducted 

under §63.772(i)(3) occurs.

(7) For each excursion, except as provided for in paragraph 

(d)(8) of this section, the owner or operator shall be deemed to 

have failed to have applied control in a manner that achieves 

the required operating parameter limits. Failure to achieve the 

required operating parameter limits is a violation of this 

standard.

(8) An excursion is not a violation of the operating 

parameter limit as specified in paragraphs (d)(8)(i) and 

(d)(8)(ii) of this section.

(i) An excursion does not count toward the number of 

excused excursions allowed under paragraph (d)(8)(ii) of this 

section when the excursion occurs during any one of the 

following periods:
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Page 116 of ???

(A) During a period of startup, shutdown, or malfunction 

when the affected facility is operated during such period in 

accordance with §63.6(e)(1); or

(B) During periods of non-operation of the unit or the 

process that is vented to the control device (resulting in 

cessation of HAP emissions to which the monitoring applies).

(ii) For each control device, or combinations of control 

devices installed on the same HAP emissions unit, one excused 

excursion is allowed per semiannual period for any reason. The 

initial semiannual period is the 6-month reporting period 

addressed by the first Periodic Report submitted by the owner or 

operator in accordance with §63.775(e) of this subpart.

(9) Nothing in paragraphs (d)(1) through (d)(8) of this 

section shall be construed to allow or excuse a monitoring 

parameter excursion caused by any activity that violates other 

applicable provisions of this subpart.

§ 63.774 Recordkeeping requirements.

(a) The recordkeeping provisions of 40 CFR part 63, subpart 

A, that apply and those that do not apply to owners and 

operators of sources subject to this subpart are listed in Table 

2 of this subpart.

(b) Except as specified in paragraphs (c), (d), and (f) of 

this section, each owner or operator of a facility subject to 
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this subpart shall maintain the records specified in paragraphs 

(b)(1) through (11) of this section:

(1) The owner or operator of an affected source subject to 

the provisions of this subpart shall maintain files of all 

information (including all reports and notifications) required 

by this subpart. The files shall be retained for at least 5 

years following the date of each occurrence, measurement, 

maintenance, corrective action, report or period.

(i) All applicable records shall be maintained in such a 

manner that they can be readily accessed.

(ii) The most recent 12 months of records shall be retained 

on site or shall be accessible from a central location by 

computer or other means that provides access within 2 hours 

after a request.

(iii) The remaining 4 years of records may be retained 

offsite.

(iv) Records may be maintained in hard copy or computerreadable form including, but not limited to, on paper, 

microfilm, computer, floppy disk, magnetic tape, or microfiche.

(2) Records specified in §63.10(b)(2);

(3) Records specified in §63.10(c) for each monitoring 

system operated by the owner or operator in accordance with the 

requirements of §63.773(d). Notwithstanding the requirements of 

§63.10(c), monitoring data recorded during periods identified in 
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paragraphs (b)(3)(i) through (b)(3)(iv) of this section shall 

not be included in any average or percent leak rate computed 

under this subpart. Records shall be kept of the times and 

durations of all such periods and any other periods during 

process or control device operation when monitors are not 

operating or failed to collect required data.

(i) Monitoring system breakdowns, repairs, calibration 

checks, and zero (low-level) and high-level adjustments;

(ii) [Reserved](ii) Startups, shutdowns, or malfunctions 

events. During startups, shutdowns, or malfunction events, the 

owner or operator shall maintain records indicating whether or 

not the startup, shutdown or malfunction plan required under 

§63.762(d), was followed.

(iii) Periods of non-operation resulting in cessation of 

the emissions to which the monitoring applies; and

(iv) Excursions due to invalid data as defined in 

§63.773(d)(6)(iv).

(4) Each owner or operator using a control device to comply 

with §63.764 of this subpart shall keep the following records 

up-to-date and readily accessible:

(i) Continuous records of the equipment operating 

parameters specified to be monitored under §63.773(d) or 

specified by the Administrator in accordance with 

§63.773(d)(3)(iii). For flares, the hourly records and records 
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of pilot flame outages specified in paragraph (e) of this 

section shall be maintained in place of continuous records.

(ii) Records of the daily average value of each 

continuously monitored parameter for each operating day 

determined according to the procedures specified in 

§63.773(d)(4) of this subpart, except as specified in paragraphs 

(b)(4)(ii)(A) and through (BC) of this section.

(A) For flares, the records required in paragraph (e) of 

this section.

(B) For condensers installed to comply with §63.765, 

records of the annual 365-day rolling average condenser 

efficiency determined under §63.772(g) shall be kept in addition 

to the daily averages.

(C) For control device whose model is tested under 

§63.772(h), the records required in paragraph (h) of this 

section.

(iii) Hourly records of whether the flow indicator 

specified under §63.771(c)(3)(i)(A) was operating and whether 

flow was detected at any time during the hour, as well as 

records of the times and durations of all periods when the vent 

stream is diverted from the control device or the monitor is not 

operating.

(iv) Where a seal or closure mechanism is used to comply 

with §63.771(c)(3)(i)(B), hourly records of flow are not 
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required. In such cases, the owner or operator shall record 

that the monthly visual inspection of the seals or closure 

mechanism has been done, and shall record the duration of all 

periods when the seal mechanism is broken, the bypass line valve 

position has changed, or the key for a lock-and-key type lock 

has been checked out, and records of any car-seal that has 

broken.

(5) Records identifying all parts of the cover or closedvent system that are designated as unsafe to inspect in 

accordance with §63.773(c)(5), an explanation of why the 

equipment is unsafe to inspect, and the plan for inspecting the 

equipment.

(6) Records identifying all parts of the cover or closedvent system that are designated as difficult to inspect in 

accordance with §63.773(c)(6), an explanation of why the 

equipment is difficult to inspect, and the plan for inspecting 

the equipment.

(7) For each inspection conducted in accordance with 

§63.773(c), during which a leak or defect is detected, a record 

of the information specified in paragraphs (b)(7)(i) through 

(b)(7)(viii) of this section.

(i) The instrument identification numbers, operator name or 

initials, and identification of the equipment.
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(ii) The date the leak or defect was detected and the date 

of the first attempt to repair the leak or defect.

(iii) Maximum instrument reading measured by the method 

specified in §63.772(c) after the leak or defect is successfully 

repaired or determined to be nonrepairable.

(iv) ―Repair delayed‖ and the reason for the delay if a 

leak or defect is not repaired within 15 calendar days after 

discovery of the leak or defect.

(v) The name, initials, or other form of identification of 

the owner or operator (or designee) whose decision it was that 

repair could not be effected without a shutdown.

(vi) The expected date of successful repair of the leak or 

defect if a leak or defect is not repaired within 15 calendar 

days.

(vii) Dates of shutdowns that occur while the equipment is 

unrepaired.

(viii) The date of successful repair of the leak or defect.

(ix) Records identifying the carbon replacement schedule 

under §63.771(d)(5) and records of each carbon replacement.

(8) For each inspection conducted in accordance with 

§63.773(c) during which no leaks or defects are detected, a 

record that the inspection was performed, the date of the 

inspection, and a statement that no leaks or defects were 

detected.
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(9) Records identifying ancillary equipment and compressors 

that are subject to and controlled under the provisions of 40 

CFR part 60, subpart KKK; 40 CFR part 61, subpart V; or 40 CFR 

part 63, subpart H.

(10) Records of glycol dehydration unit baseline operations 

calculated as required under §63.771(e)(1).

(11) Records required in §63.771(e)(3)(i) documenting that 

the facility continues to operate under the conditions specified 

in §63.771(e)(2).

(c) An owner or operator that elects to comply with the 

benzene emission limit specified in §63.765(b)(1)(ii) shall 

document, to the Administrator's satisfaction, the following 

items:

(1) The method used for achieving compliance and the basis 

for using this compliance method; and

(2) The method used for demonstrating compliance with 0.90 

megagrams per year of benzene.

(3) Any information necessary to demonstrate compliance as 

required in the methods specified in paragraphs (c)(1) and 

(c)(2) of this section.

(d)(1) An owner or operator of a glycol dehydration unit 

that meets the exemption criteria in §63.764(e)(1)(i) or 

§63.764(e)(1)(ii) shall maintain the records specified in 
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paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as 

appropriate, for that glycol dehydration unit.

(i) The actual annual average natural gas throughput (in 

terms of natural gas flowrate to the glycol dehydration unit per 

day) as determined in accordance with §63.772(b)(1), or

(ii) The actual average benzene emissions (in terms of 

benzene emissions per year) as determined in accordance with 

§63.772(b)(2).

(2) An owner or operator that is exempt from the control 

requirements under §63.764(e)(2) of this subpart shall maintain 

the following records:

(i) Information and data used to demonstrate that a piece 

of ancillary equipment or a compressor is not in VHAP service or 

not in wet gas service shall be recorded in a log that is kept 

in a readily accessible location.

(ii) Identification and location of ancillary equipment or 

compressors, located at a natural gas processing plant subject 

to this subpart, that is in VHAP service less than 300 hours per 

year.

(e) Record the following when using a flare to comply with 

§63.771(d):

(1) Flare design (i.e., steam-assisted, air-assisted, or 

non-assisted);
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(2) All visible emission readings, heat content 

determinations, flowrate measurements, and exit velocity 

determinations made during the compliance determination required 

by §63.772(e)(2); and

(3) All hourly records and other recorded periods when the 

pilot flame is absent.

(f) The owner or operator of an area source not located 

within a UA plus offset and UC boundary must keep a record of 

the calculation used to determine the optimum glycol circulation 

rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), 

as applicable.

(g) The owner or operator of an affected source subject to 

this subpart shall maintain records of the occurrence and 

duration of each malfunction of operation (i.e., process 

equipment) or the air pollution control equipment and monitoring 

equipment. The owner or operator shall maintain records of 

actions taken during periods of malfunction to minimize 

emissions in accordance with §63.764(a), including corrective 

actions to restore malfunctioning process and air pollution 

control and monitoring equipment to its normal or usual manner 

of operation.

(h) Record the following when using a control device whose 

model is tested under §63.772(h) to comply with §63.771(d), 

(e)(3)(ii) and (f)(1):
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(1) All visible emission readings and flowrate measurements

made during the compliance determination required by §63.772(i); 

and

(2) All hourly records and other recorded periods when the 

pilot flame is absent.

(i) The date the semi-annual maintenance inspection 

required under §63.773(b) is performed. Include a list of any 

modifications or repairs made to the control device during the

inspection and other maintenance performed such as cleaning of

the fuel nozzles.

§63.775 Reporting requirements.

(a) The reporting provisions of subpart A of this part, 

that apply and those that do not apply to owners and operators 

of sources subject to this subpart are listed in Table 2 of this

subpart.

(b) Each owner or operator of a major source subject to 

this subpart shall submit the information listed in paragraphs 

(b)(1) through (b)(6) of this section, except as provided in 

paragraphs (b)(7) and (b)(8) of this section.

(1) The initial notifications required for existing 

affected sources under §63.9(b)(2) shall be submitted as 

provided in paragraphs (b)(1)(i) and (ii) of this section.

(i) Except as otherwise provided in paragraph (ii), the 

initial notifications shall be submitted by 1 year after an 
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affected source becomes subject to the provisions of this 

subpart or by June 17, 2000, whichever is later. Affected 

sources that are major sources on or before June 17, 2000 and 

plan to be area sources by June 17, 2002 shall include in this 

notification a brief, nonbinding description of a schedule for 

the action(s) that are planned to achieve area source status. 

(ii) An affected source identified under §63.760(f)(7) or 

(9) shall submit an initial notification required for existing 

affected sources under §63.9(b)(2) within 1 year after the 

affected source becomes subject to the provisions of this 

subpart or by one year after publication of the final rule in 

the Federal Register, whichever is later. An affected source 

identified under §63.760(f)(7) or (9) that plans to be an area 

source by three years after publication of the final rule in the 

Federal Register, shall include in this notification a brief, 

nonbinding description of a schedule for the action(s) that are 

planned to achieve area source status.

(2) The date of the performance evaluation as specified in 

§63.8(e)(2), required only if the owner or operator is required 

by the Administrator to conduct a performance evaluation for a 

continuous monitoring system. A separate notification of the 

performance evaluation is not required if it is included in the 

initial notification submitted in accordance with paragraph 

(b)(1) of this section.
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(3) The planned date of a performance test at least 60 days 

before the test in accordance with §63.7(b). Unless requested 

by the Administrator, a site-specific test plan is not required 

by this subpart. If requested by the Administrator, the owner 

or operator must also submit the site-specific test plan 

required by §63.7(c) with the notification of the performance 

test. A separate notification of the performance test is not 

required if it is included in the initial notification submitted 

in accordance with paragraph (b)(1) of this section.

(4) A Notification of Compliance Status report as described 

in paragraph (d) of this section;

(5) Periodic Reports as described in paragraph (e) of this 

section; and

(6) If there was a malfunction during the reporting period, 

the Periodic Report specified in paragraph (e) of this section 

shall include the number, duration, and a brief description for 

each type of malfunction which occurred during the reporting 

period and which caused or may have caused any applicable 

emission limitation to be exceeded. The report must also 

include a description of actions taken by an owner or operator 

during a malfunction of an affected source to minimize emissions 

in accordance with §63.764(j), including actions taken to 

correct a malfunction.Startup, shutdown, and malfunction reports 

specified in §63.10(d)(5) shall be submitted as required. 
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Separate startup, shutdown, and malfunction reports as described 

in §63.10(d)(5) are not required if the information is included 

in the Periodic Report specified in paragraph (e) of this 

section.

(7) Each owner or operator of a glycol dehydration unit 

subject to this subpart that is exempt from the control 

requirements for glycol dehydration unit process vents in 

§63.765, is exempt from all reporting requirements for major 

sources in this subpart, for that unit.[Reserved]

(8) Each owner or operator of ancillary equipment and 

compressors subject to this subpart that are exempt from the 

control requirements for equipment leaks in §63.769, are exempt 

from all reporting requirements for major sources in this 

subpart, for that equipment.

(c) Except as provided in paragraph (c)(8), each owner or 

operator of an area source subject to this subpart shall submit 

the information listed in paragraph (c)(1) of this section. If 

the source is located within a UA plus offset and UC boundary, 

the owner or operator shall also submit the information listed 

in paragraphs (c)(2) through (6) of this section. If the source 

is not located within any UA plus offset and UC boundaries, the 

owner or operator shall also submit the information listed 

within paragraph (c)(7).
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(1) The initial notifications required under §63.9(b)(2) 

not later than January 3, 2008. In addition to submitting your 

initial notification to the addressees specified under §63.9(a), 

you must also submit a copy of the initial notification to EPA's 

Office of Air Quality Planning and Standards. Send your 

notification via e-mail to CCG-ONGOil and Gas Sector@EPA.GOV or 

via U.S. mail or other mail delivery service to U.S. EPA, Sector 

Policies and Programs Division/Coatings and ChemicalsFuels and 

Incineration Group (E143–01), Attn: Oil and Gas Project Leader, 

Research Triangle Park, NC 27711.

(2) The date of the performance evaluation as specified in 

§63.8(e)(2) if an owner or operator is required by the 

Administrator to conduct a performance evaluation for a 

continuous monitoring system.

(3) The planned date of a performance test at least 60 days 

before the test in accordance with §63.7(b). Unless requested 

by the Administrator, a site-specific test plan is not required 

by this subpart. If requested by the Administrator, the owner 

or operator must submit the site-specific test plan required by 

§63.7(c) with the notification of the performance test. A 

separate notification of the performance test is not required if 

it is included in the initial notification submitted in 

accordance with paragraph (c)(1) of this section.
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(4) A Notification of Compliance Status as described in 

paragraph (d) of this section;

(5) Periodic reports as described in paragraph (e)(3) of 

this section; and

(6) If there was a malfunction during the reporting period, 

the Periodic Report specified in paragraph (e) of this section 

shall include the number, duration, and a brief description for 

each type of malfunction which occurred during the reporting 

period and which caused or may have caused any applicable 

emission limitation to be exceeded. The report must also 

include a description of actions taken by an owner or operator 

during a malfunction of an affected source to minimize emissions 

in accordance with §63.764(j), including actions taken to 

correct a malfunction.Startup, shutdown, and malfunction reports 

specified in §63.10(d)(5). Separate startup, shutdown, and 

malfunction reports as described in §63.10(d)(5) are not 

required if the information is included in the Periodic Report 

specified in paragraph (e) of this section.

(7) The information listed in paragraphs (c)(1)(i) through 

(v) of this section. This information shall be submitted with 

the initial notification.

(i) Documentation of the source's location relative to the 

nearest UA plus offset and UC boundaries. This information 

shall include the latitude and longitude of the affected source; 
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whether the source is located in an urban cluster with 10,000 

people or more; the distance in miles to the nearest urbanized 

area boundary if the source is not located in an urban cluster 

with 10,000 people or more; and the names of the nearest urban 

cluster with 10,000 people or more and nearest urbanized area.

(ii) Calculation of the optimum glycol circulation rate 

determined in accordance with §63.764(d)(2)(i).

(iii) If applicable, documentation of the alternate glycol 

circulation rate calculated using GRI-GLYCalcTM , Version 3.0 or 

higher and documentation stating why the TEG dehydration unit 

must operate using the alternate glycol circulation rate.

(iv) The name of the manufacturer and the model number of 

the glycol circulation pump(s) in operation.

(v) Statement by a responsible official, with that 

official's name, title, and signature, certifying that the 

facility will always operate the glycol dehydration unit using 

the optimum circulation rate determined in accordance with 

§63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable.

(8) An owner or operator of a TEG dehydration unit located 

at an area source that meets the criteria in §63.764(e)(1)(i) or 

§63.764(e)(1)(ii) is exempt from the reporting requirements for 

area sources in paragraphs (c)(1) through (7) of this section, 

for that unit.
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(d) Each owner or operator of a source subject to this

subpart shall submit a Notification of Compliance Status Report 

as required under §63.9(h) within 180 days after the compliance 

date specified in §63.760(f). In addition to the information 

required under §63.9(h), the Notification of Compliance Status 

Report shall include the information specified in paragraphs 

(d)(1) through (12) of this section. This information may be 

submitted in an operating permit application, in an amendment to 

an operating permit application, in a separate submittal, or in 

any combination of the three. If all of the information 

required under this paragraph has been submitted at any time 

prior to 180 days after the applicable compliance dates 

specified in §63.760(f), a separate Notification of Compliance 

Status Report is not required. If an owner or operator submits 

the information specified in paragraphs (d)(1) through (12) of 

this section at different times, and/or different submittals, 

subsequent submittals may refer to previous submittals instead 

of duplicating and resubmitting the previously submitted 

information.

(1) If a closed-vent system and a control device other than 

a flare are used to comply with §63.764, the owner or operator 

shall submit the information in paragraph (d)(1)(iii) of this 

section and the information in either paragraph (d)(1)(i) or 

(ii) of this section.
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(i) The condenser design analysis documentation specified 

in §63.772(e)(4) of this subpart, if the owner or operator 

elects to prepare a design analysis.

(ii) If the owner or operator elects is required to conduct 

a performance test, the performance test results including the 

information specified in paragraphs (d)(1)(ii)(A) and (B) of 

this section. Results of a performance test conducted prior to 

the compliance date of this subpart can be used provided that 

the test was conducted using the methods specified in 

§63.772(e)(3) and that the test conditions are representative of 

current operating conditions. If the owner or operator operates 

a combustion control device model tested under §63.772(h), an 

electronic copy of the performance test results shall be 

submitted via email to Oil and Gas PT@EPA.GOV.

(A) The percent reduction of HAP or TOC, or the outlet 

concentration of HAP or TOC (parts per million by volume on a 

dry basis), determined as specified in §63.772(e)(3) of this 

subpart; and

(B) The value of the monitored parameters specified in 

§773(d) of this subpart, or a site-specific parameter approved 

by the permitting agency, averaged over the full period of the 

performance test.
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(iii) The results of the closed-vent system initial 

inspections performed according to the requirements in 

§63.773(c)(2)(i) and (ii).

(2) If a closed-vent system and a flare are used to comply 

with §63.764, the owner or operator shall submit performance 

test results including the information in paragraphs (d)(2)(i) 

and (ii) of this section. The owner or operator shall also 

submit the information in paragraph (d)(2)(iii) of this section.

(i) All visible emission readings, heat content 

determinations, flowrate measurements, and exit velocity 

determinations made during the compliance determination required 

by §63.772(e)(2) of this subpart.

(ii) A statement of whether a flame was present at the 

pilot light over the full period of the compliance 

determination.

(iii) The results of the closed-vent system initial 

inspections performed according to the requirements in 

§63.773(c)(2)(i) and (ii).

(3) For each owner or operator subject to the provisions 

specified in §63.769, the owner or operator shall submit the 

information required by §61.247(a), except that the initial 

report required in §61.247(a) shall be submitted as a part of 

the Notification of Compliance Status Report required in 

paragraph (d) of this section. The owner or operator shall also 
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submit the information specified in paragraphs (d)(3)(i) and 

(ii) of this section.

(i) The number of each equipment (e.g., valves, pumps, 

etc.) excluding equipment in vacuum service, and

(ii) Any change in the information submitted in this 

paragraph shall be provided to the Administrator as a part of 

subsequent Periodic Reports described in paragraph (e)(2)(iv) of 

this section.

(4) The owner or operator shall submit one complete test 

report for each test method used for a particular source.

(i) For additional tests performed using the same test 

method, the results specified in paragraph (d)(1)(ii) of this 

section shall be submitted, but a complete test report is not 

required.

(ii) A complete test report shall include a sampling site 

description, description of sampling and analysis procedures and 

any modifications to standard procedures, quality assurance 

procedures, record of operating conditions during the test, 

record of preparation of standards, record of calibrations, raw 

data sheets for field sampling, raw data sheets for field and 

laboratory analyses, documentation of calculations, and any 

other information required by the test method.

(5) For each control device other than a flare used to meet 

the requirements of §63.764, the owner or operator shall submit 
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the information specified in paragraphs (d)(5) (i) through (iii) 

of this section for each operating parameter required to be 

monitored in accordance with the requirements of §63.773(d).

(i) The minimum operating parameter value or maximum 

operating parameter value, as appropriate for the control 

device, established by the owner or operator to define the 

conditions at which the control device must be operated to 

continuously achieve the applicable performance requirements of 

§63.771(d)(1) or (e)(3)(ii).

(ii) An explanation of the rationale for why the owner or 

operator selected each of the operating parameter values 

established in §63.773(d)(5). This explanation shall include 

any data and calculations used to develop the value and a 

description of why the chosen value indicates that the control 

device is operating in accordance with the applicable 

requirements of §63.771(d)(1), or § 63.771(e)(3)(ii) or (f)(1).

(iii) A definition of the source's operating day for 

purposes of determining daily average values of monitored 

parameters. The definition shall specify the times at which an 

operating day begins and ends.

(iv) For each carbon adsorber, the predetermined carbon 

replacement schedule as required in §63.771(d)(5)(i).
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(6) Results of any continuous monitoring system performance 

evaluations shall be included in the Notification of Compliance 

Status Report.

(7) After a title V permit has been issued to the owner or 

operator of an affected source, the owner or operator of such 

source shall comply with all requirements for compliance status 

reports contained in the source's title V permit, including 

reports required under this subpart. After a title V permit has 

been issued to the owner or operator of an affected source, and 

each time a notification of compliance status is required under 

this subpart, the owner or operator of such source shall submit 

the notification of compliance status to the appropriate 

permitting authority following completion of the relevant 

compliance demonstration activity specified in this subpart.

(8) The owner or operator that elects to comply with the 

requirements of §63.765(b)(1)(ii) shall submit the records 

required under §63.774(c).

(9) The owner or operator shall submit the analysis 

performed under §63.760(a)(1).

(10) The owner or operator shall submit a statement as to 

whether the source has complied with the requirements of this 

subpart.

(11) The owner or operator shall submit the analysis 

prepared under §63.771(e)(2) to demonstrate the conditions by 
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which the facility will be operated to achieve an overallthe HAP 

emission reduction of 95.0 percent, or the BTEX limit in 

§63.765(b)(1)(iii), through process modifications or a 

combination of process modifications and one or more control 

devices.

(12) If a cover is installed to comply with §63.764, the 

results of the initial inspection performed according to the 

requirements specified in §63.773(c)(2)(iii).

(13) If the owner or operator installs a combustion 

control device model tested under the procedures in §63.772(h), 

the data listed under §63.772(h)(8).

(14) For each combustion control device model tested under 

§63.772(h), the information listed in paragraphs (d)(14)(i) 

through (vi) of this section.

(i) Name, address and telephone number of the control 

device manufacturer.

(ii) Control device model number.

(iii) Control device serial number.

(iv) Date of control device performance test.

(v) Manufacturer’s HAP destruction efficiency rating.

(vi) Control device operating parameters, maximum allowable

inlet gas flow rate.

(e) Periodic Reports. An owner or operator of a major 

source shall prepare Periodic Reports in accordance with 
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paragraphs (e) (1) and (2) of this section and submit them to 

the Administrator. An owner or operator of an area source shall 

prepare Periodic Reports in accordance with paragraph (e)(3) of 

this section and submit them to the Administrator.

(1) An owner or operator shall submit Periodic Reports 

semiannually beginning 60 calendar days after the end of the 

applicable reporting period. The first report shall be 

submitted no later than 240 days after the date the Notification 

of Compliance Status Report is due and shall cover the 6-month 

period beginning on the date the Notification of Compliance 

Status Report is due.

(2) The owner or operator shall include the information 

specified in paragraphs (e)(2)(i) through (xiii) of this 

section, as applicable.

(i) The information required under §63.10(e)(3). For the 

purposes of this subpart and the information required under 

§63.10(e)(3), excursions (as defined in §63.773(d)(6)) shall be 

considered excess emissions.

(ii) A description of all excursions as defined in 

§63.773(d)(6) of this subpart that have occurred during the 6-

month reporting period.

(A) For each excursion caused when the daily average value 

of a monitored operating parameter is less than the minimum 

operating parameter limit (or, if applicable, greater than the 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 140 of ???

maximum operating parameter limit), as specified in 

§63.773(d)(6)(i), the report must include the daily average 

values of the monitored parameter, the applicable operating 

parameter limit, and the date and duration of the period that 

the excursion occurred.

(B) For each excursion caused when the 365-day average 

condenser control efficiency is less than 95.0 percentthe value,

as specified in §63.773(d)(6)(ii), the report must include the 

365-day average values of the condenser control efficiency, and 

the date and duration of the period that the excursion occurred.

(C) For each excursion caused when condenser control 

efficiency is less than 90.0 percent, as calculated according to 

the procedures specified in §63.772(g)(2)(iii) (A) or (B)the 

value specified in §63.773(d)(6)(iii), the report must include 

the average values of the condenser control efficiency, and the 

date and duration of the period that the excursion occurred.

(D) For each excursion caused by the lack of monitoring 

data, as specified in §63.773(d)(6)(iv), the report must include 

the date and duration of the period when the monitoring data 

were not collected and the reason why the data were not 

collected.

(E) For each excursion caused when the maximum inlet gas 

flow rate identified under §63.772(h) is exceeded, the report 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 141 of ???

must include the values of the inlet gas identified and the date 

and duration of the period that the excursion occurred.

(F) For each excursion caused when visible emissions 

determined under §63.772(i) exceed the maximum allowable 

duration, the report must include the date and duration of the 

period that the excursion occurred. 

(iii) For each inspection conducted in accordance with 

§63.773(c) during which a leak or defect is detected, the 

records specified in §63.774(b)(7) must be included in the next 

Periodic Report.

(iv) For each owner or operator subject to the provisions 

specified in §63.769, the owner or operator shall comply with 

the reporting requirements specified in 40 CFR 61.247, except 

that the Periodic Reports shall be submitted on the schedule 

specified in paragraph (e)(1) of this section.

(v) For each closed-vent system with a bypass line subject 

to §63.771(c)(3)(i)(A), records required under 

§63.774(b)(4)(iii) of all periods when the vent stream is 

diverted from the control device through a bypass line. For 

each closed-vent system with a bypass line subject to 

§63.771(c)(3)(i)(B), records required under §63.774(b)(4)(iv) of 

all periods in which the seal mechanism is broken, the bypass 

valve position has changed, or the key to unlock the bypass line 

valve was checked out.
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(vi) If an owner or operator elects to comply with 

§63.765(b)(1)(ii), the records required under §63.774(c)(3).

(vii) The information in paragraphs (e)(2)(vii) (A) and (B) 

of this section shall be stated in the Periodic Report, when 

applicable.

(A) No excursions.

(B) No continuous monitoring system has been inoperative, 

out of control, repaired, or adjusted.

(viii) Any change in compliance methods as specified in 

§63.772(f).

(ix) If the owner or operator elects to comply with 

§63.765(c)(2), the records required under §63.774(b)(11).

(x) For flares, the records specified in §63.774(e)(3).

(xi) The results of any periodic test as required in 

§63.772(e)(3) conducted during the reporting period.

(xii) For each carbon adsorber used to meet the control 

device requirements of §63.771(d)(1), records of each carbon 

replacement that occurred during the reporting period.

(xiii) For combustion control device inspections conducted 

in accordance with §63.773(b) the records specified in 

§63.774(i). 

(3) An owner or operator of an area source located inside a 

UA plus offset and UC boundary shall prepare and submit Periodic 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 143 of ???

Reports in accordance with paragraphs (e)(3)(i) through (iii) of 

this section.

(i) Periodic reports must be submitted on an annual basis. 

The first reporting period shall cover the period beginning on 

the date the Notification of Compliance Status Report is due and 

ending on December 31. The report shall be submitted within 30 

days after the end of the reporting period.

(ii) Subsequent reporting periods begin every January 1 and 

end on December 31. Subsequent reports shall be submitted 

within 30 days following the end of the reporting period.

(iii) The periodic reports must contain the information 

included in paragraph (e)(2) of this section.

(f) Notification of process change. Whenever a process 

change is made, or a change in any of the information submitted 

in the Notification of Compliance Status Report, the owner or 

operator shall submit a report within 180 days after the process 

change is made or as a part of the next Periodic Report as 

required under paragraph (e) of this section, whichever is 

sooner. The report shall include:

(1) A brief description of the process change;

(2) A description of any modification to standard 

procedures or quality assurance procedures;
Proposed Subpart HH Redline/Strikeout July 28, 2011

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(3) Revisions to any of the information reported in the 

original Notification of Compliance Status Report under 

paragraph (d) of this section; and

(4) Information required by the Notification of Compliance 

Status Report under paragraph (d) of this section for changes 

involving the addition of processes or equipment.

(g) Electronic Reporting. (1) As of January 1, 2012 and 

within 60 days after the date of completing each performance 

test, as defined in §63.2 and as required in this subpart, you 

must submit performance test data, except opacity data, 

electronically to EPA’s Central Data Exchange (CDX) by using the 

Electronic Reporting Tool (ERT) (see 

http://www.epa.gov/ttn/chief/ert/ert tool.html/). Only data 

collected using test methods compatible with ERT are subject to 

this requirement to be submitted electronically into EPA’s 

WebFIRE database. 

(2) All reports required by this subpart not subject to 

the requirements in paragraphs (g)(1) of this section must be 

sent to the Administrator at the appropriate address listed in 

§63.13. If acceptable to both the Administrator and the owner 

or operator of a source, these reports may be submitted on 

electronic media. The Administrator retains the right to 

require submittal of reports subject to paragraph (g)(1) of this 

section in paper format.
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§ 63.776 Implementation and enforcement.

(a) This subpart can be implemented and enforced by the 

U.S. EPA, or a delegated authority such as the applicable State, 

local, or Tribal agency. If the U.S. EPA Administrator has 

delegated authority to a State, local, or Tribal agency, then 

that agency, in addition to the U.S. EPA, has the authority to 

implement and enforce this subpart. Contact the applicable U.S. 

EPA Regional Office to find out if this subpart is delegated to 

a State, local, or Tribal agency.

(b) In delegating implementation and enforcement authority 

of this subpart to a State, local, or Tribal agency under 

subpart E of this part, the authorities contained in paragraph 

(c) of this section are retained by the Administrator of U.S. 

EPA and cannot be transferred to the State, local, or Tribal 

agency.

(c) The authorities that cannot be delegated to State, 

local, or Tribal agencies are as specified in paragraphs (c)(1) 

through (4) of this section.

(1) Approval of alternatives to the requirements in 

§§63.760, 63.764 through 63.766, 63.769, 63.771, and 63.777.

(2) Approval of major alternatives to test methods under 

§63.7(e)(2)(ii) and (f), as defined in §63.90, and as required 

in this subpart.
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(3) Approval of major alternatives to monitoring under 

§63.8(f), as defined in §63.90, and as required in this subpart.

(4) Approval of major alternatives to recordkeeping and 

reporting under §63.10(f), as defined in §63.90, and as required 

in this subpart.

§ 63.777 Alternative means of emission limitation.

(a) If, in the judgment of the Administrator, an 

alternative means of emission limitation will achieve a 

reduction in HAP emissions at least equivalent to the reduction 

in HAP emissions from that source achieved under the applicable 

requirements in §§63.764 through 63.771, the Administrator will 

publish in the Federal Register a notice permitting the use of 

the alternative means for purposes of compliance with that 

requirement. The notice may condition the permission on 

requirements related to the operation and maintenance of the 

alternative means.

(b) Any notice under paragraph (a) of this section shall be 

published only after public notice and an opportunity for a 

hearing.

(c) Any person seeking permission to use an alternative 

means of compliance under this section shall collect, verify, 

and submit to the Administrator information demonstrating that 

the alternative achieves equivalent emission reductions.

§§ 63.778-63.779 [Reserved]
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Appendix to Subpart HH of Part 63—Tables

Table 1 to Subpart HH of Part 63—List of Hazardous Air 

Pollutants for Subpart HH

CAS Numbera Chemical name

75070 Acetaldehyde

71432 Benzene (includes benzene in gasoline)

75150 Carbon disulfide

463581 Carbonyl sulfide

100414 Ethyl benzene

107211 Ethylene glycol

50000 Formaldehyde

110543 n-Hexane

91203 Naphthalene

108883 Toluene

540841 2,2,4-Trimethylpentane

1330207 Xylenes (isomers and mixture)

95476 o-Xylene

108383 m-Xylene

106423 p-Xylene

aCAS numbers refer to the Chemical Abstracts Services registry 

number assigned to specific compounds, isomers, or mixtures of 

compounds.

Table 2 to Subpart HH of Part 63—Applicability of 40 CFR Part 63 

General Provisions to Subpart HH

General provisions 

reference

Applicable 

to subpart 

HH Explanation

§63.1(a)(1) Yes.

§63.1(a)(2) Yes.

§63.1(a)(3) Yes.

§63.1(a)(4) Yes.

§63.1(a)(5) No Section reserved.

§63.1(a)(6) Yes.

§63.1(a)(7) through No Section reserved.
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(a)(9)

§63.1(a)(10) Yes.

§63.1(a)(11) Yes.

§63.1(a)(12) Yes.

§63.1(b)(1) No Subpart HH specifies 

applicability.

§63.1(b)(2) No Section reserved.

§63.1(b)(3) Yes.

§63.1(c)(1) No Subpart HH specifies 

applicability.

§63.1(c)(2) Yes. Subpart HH exempts area sources 

from the requirement to obtain a 

Title V permit unless otherwise 

required by law as specified in 

§63.760(h).

§63.1(c)(3) and 

(c)(4)

No Section reserved.

§63.1(c)(5) Yes.

§63.1(d) No Section reserved.

§63.1(e) Yes.

§63.2 Yes. Except definition of major 

source is unique for this source 

category and there are 

additional definitions in 

subpart HH.

§63.3(a) through (c) Yes.

§63.4(a)(1) through 

(a)(2)

Yes.

§63.4(a)(3) through 

(a)(5)

No Section reserved.

§63.4(b) Yes.

§63.4(c) Yes.

§63.5(a)(1) Yes.

§63.5(a)(2) Yes.

§63.5(b)(1) Yes.

§63.5(b)(2) No Section reserved.

§63.5(b)(3) Yes.

§63.5(b)(4) Yes.

§63.5(b)(5) No Section Reserved.

§63.5(b)(6) Yes.

§63.5(c) No Section reserved.

§63.5(d)(1) Yes.

§63.5(d)(2) Yes.

§63.5(d)(3) Yes.

§63.5(d)(4) Yes.

§63.5(e) Yes.

§63.5(f)(1) Yes.
Proposed Subpart HH Redline/Strikeout July 28, 2011

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§63.5(f)(2) Yes.

§63.6(a) Yes.

§63.6(b)(1) Yes.

§63.6(b)(2) Yes.

§63.6(b)(3) Yes.

§63.6(b)(4) Yes.

§63.6(b)(5) Yes.

§63.6(b)(6) No Section reserved.

§63.6(b)(7) Yes.

§63.6(c)(1) Yes.

§63.6(c)(2) Yes.

§63.6(c)(3) through 

(c)(4)

No Section reserved.

§63.6(c)(5) Yes.

§63.6(d) No Section reserved.

§63.6(e) Yes.

§63.6(e)(1)(i) No See Except as otherwise 

specified. Addressed in 

§63.7624(j) for general duty 

requirement.

§63.6(e)(1)(ii) Yes.No

§63.6(e)(1)(iii) Yes.

§63.6(e)(2) No Section reserved.

§63.6(e)(3)(i) Yes.No Sources exempt under §63.764(e) 

and sources located outside UA 

plus offset and UC boundaries 

are not required to develop 

startup, shutdown, and 

malfunction plans as stated in 

§63.762(e).

§63.6(e)(3)(i)(A) No Except as otherwise specified. 

Addressed in §63.762(c).

§63.6(e)(3)(i)(B) Yes.

§63.6(e)(3)(i)(C) Yes.

§63.6(e)(3)(ii) No Section reserved.

§63.6(e)(3)(iii) 

through (3)(vi)

Yes.

§63.6(e)(3)(vii) Yes.

§63.6(e)(3)(vii) (A) Yes.

§63.6(e)(3)(vii) (B) Yes Except that the plan must 

provide for operation in 

compliance with §63.762(c).

§63.6(e)(3)(viii) 

through (ix)

Yes.

§63.6(f)(1) Yes.No.

§63.6(f)(2) Yes.

§63.6(f)(3) Yes.
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§63.6(g) Yes.

§63.6(h) No Subpart HH does not contain 

opacity or visible emission 

standards.

§63.6(i)(1) through 

(i)(14)

Yes.

§63.6(i)(15) No Section reserved.

§63.6(i)(16) Yes.

§63.6(j) Yes.

§63.7(a)(1) Yes.

§63.7(a)(2) Yes But the performance test results 

must be submitted within 180 

days after the compliance date.

§63.7(a)(3) Yes.

§63.7(b) Yes.

§63.7(c) Yes.

§63.7(d) Yes.

§63.7(e)(1) YesNo.

§63.7(e)(2) Yes.

§63.7(e)(3) Yes.

§63.7(e)(4) Yes.

§63.7(f) Yes.

§63.7(g) Yes.

§63.7(h) Yes.

§63.8(a)(1) Yes.

§63.8(a)(2) Yes.

§63.8(a)(3) No Section reserved.

§63.8(a)(4) Yes.

§63.8(b)(1) Yes.

§63.8(b)(2) Yes.

§63.8(b)(3) Yes.

§63.8(c)(1) Yes.

§63.8(c)(1)(i) No.

§63.8(c)(1)(ii) Yes.

§63.8(c)(1)(iii) Pending.

§63.8(c)(2) Yes.

§63.8(c)(3) Yes.

§63.8(c)(4) Yes.

§63.8(c)(4)(i) No Subpart HH does not require 

continuous opacity monitors.

§63.8(c)(4)(ii) Yes.

§63.8(c)(5) through 

(c)(8)

Yes.

§63.8(d) Yes.

§63.8(d)(3) Yes Except for last sentence, which 

refers to an SSM plan. SSM 

plans are not required.
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§63.8(e) Yes Subpart HH does not specifically 

require continuous emissions 

monitor performance evaluation, 

however, the Administrator can 

request that one be conducted.

§63.8(f)(1) through 

(f)(5)

Yes.

§63.8(f)(6) Yes.

§63.8(g) No Subpart HH specifies continuous 

monitoring system data reduction 

requirements.

§63.9(a) Yes.

§63.9(b)(1) Yes.

§63.9(b)(2) Yes Existing sources are given 1 

year (rather than 120 days) to 

submit this notification. Major 

and area sources that meet 

§63.764(e) do not have to submit 

initial notifications.

§63.9(b)(3) No Section reserved.

§63.9(b)(4) Yes.

§63.9(b)(5) Yes.

§63.9(c) Yes.

§63.9(d) Yes.

§63.9(e) Yes.

§63.9(f) No Subpart HH does not have opacity 

or visible emission standards.

§63.9(g)(1) Yes.

§63.9(g)(2) No Subpart HH does not have opacity 

or visible emission standards.

§63.9(g)(3) Yes.

§63.9(h)(1) through 

(h)(3)

Yes Area sources located outside UA 

plus offset and UC boundaries 

are not required to submit 

notifications of compliance 

status.

§63.9(h)(4) No Section reserved.

§63.9(h)(5) through 

(h)(6)

Yes.

§63.9(i) Yes.

§63.9(j) Yes.

§63.10(a) Yes.

§63.10(b)(1) Yes. §63.774(b)(1) requires sources 

to maintain the most recent 12 

months of data on site and 

allows offsite storage for the 

remaining 4 years of data.
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§63.10(b)(2) Yes.

§63.10(b)(2)(i) No.

§63.10(b)(2)(ii) No See §63.774(g) for recordkeeping 

of occurrence, duration, and 

actions taken during 

malfunctions.

§63.10(b)(2)(iii) Yes.

§63.10(b)(2)(iv)

through (b)(2)(v)

No.

§63.10(b)(2)(vi)

through (b)(2)(xiv)

Yes.

§63.10(b)(3) Yes §63.774(b)(1) requires sources 

to maintain the most recent 12 

months of data on site and 

allows offsite storage for the 

remaining 4 years of data.

§63.10(c)(1) Yes.

§63.10(c)(2) through 

(c)(4)

No Sections reserved.

§63.10(c)(5) through 

(c)(8)

Yes.

§63.10(c)(9) No Section reserved.

§63.10(c)(10)through 

(11) through(c)(15)

Yes.No See §63.774(g) for recordkeeping 

of malfunctions.

§63.10(c)(12) 

through(c)(14)

Yes.

§63.10(c)(15) No.

§63.10(d)(1) Yes.

§63.10(d)(2) Yes Area sources located outside UA 

plus offset and UC boundaries do 

not have to submit performance 

test reports.

§63.10(d)(3) Yes.

§63.10(d)(4) Yes.

§63.10(d)(5)(i) YesNo See §63.775(b)(6) or (c)(6) for 

reporting of 

malfunctions.Subpart HH requires 

major sources to submit a 

startup, shutdown, and 

malfunction report semiannually. Area sources located 

within UA plus offset and UC 

boundaries are required to 

submit startup, shutdown, and 

malfunction reports annually. 

Area sources located outside UA 

plus offset and UC boundaries 
Proposed Subpart HH Redline/Strikeout July 28, 2011

Page 153 of ???

are not required to submit 

startup, shutdown, and 

malfunction reports.

§63.10(e)(1) Yes Area sources located outside UA 

plus offset and UC boundaries 

are not required to submit 

reports.

§63.10(e)(2) Yes Area sources located outside UA 

plus offset and UC boundaries 

are not required to submit 

reports.

§63.10(e)(3)(i) Yes Subpart HH requires major 

sources to submit Periodic 

Reports semi-annually. Area 

sources are required to submit 

Periodic Reports annually. Area 

sources located outside UA plus 

offset and UC boundaries are not 

required to submit reports.

§63.10(e)(3)(i)(A) Yes.

§63.10(e)(3)(i)(B) Yes.

§63.10(e)(3)(i)(C) No Section reserved.

§63.10(e)(3)(ii) 

through (viii)

Yes.

§63.10(f) Yes.

§63.11(a) and (b) Yes.

§63.11(c), (d), and 

(e)

Yes.

§63.12(a) through (c) Yes.

§63.13(a) through (c) Yes.

§63.14(a) and (b) Yes.

§63.15(a) and (b) Yes.

§63.16 Yes.