COMPARISON OF 1999 MACT STANDARDS FOR THE OIL AND NATURAL GAS 

SECTOR TO THE 2012 MACT STANDARDS

The attached files compare the 1999 MACT standards for the Oil and Natural Gas Sector 

(40 CFR part 63, subparts HH and HHH) to the 2012 standards. The redline/strikeout markings 

show the revisions that have been made to the 1999 standards. 

These files are provided as a courtesy to the reader and should not be considered authoritative.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 1 of 157

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 limitations 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 2 of 157

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[INSERT DATE OF PUBLICATION IN THE 

FEDERAL REGISTER], 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, 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 3 of 157

1999 [INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER], 

multiplied by a factor of 1.2. 

 (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

[INSERT DATE OF PUBLICATON IN THE FEDERAL REGISTER], 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 4 of 157

dehydration units, the glycol circulation rate used in the 

calculation shall be the unit’s maximum rate under its physical 

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.

 (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 as specified in paragraphs 

(b)(1)(i)(A) through (C) of this section.;
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 5 of 157

 (A) Each large glycol dehydration unit;

 (B) Each small glycol dehydration unit for which 

construction commenced on or before August 23, 2011, is an 

existing small glycol dehydration unit; and

 (C) Each small glycol dehydration unit for which 

construction commenced after August 23, 2011, is a new small 

glycol dehydration unit.

 (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] Any source that determines it is not a major 

source but has actual emissions of 5 tons per year or more of a 

single HAP, or 12.5 tons per year or more of a combination of 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 6 of 157

HAPs (i.e., 50 percent of the major source thresholds), shall 

update its major source determination within one year of the 

prior determination or [Date of Publication in the Federal 

Register], whichever is later, and each year thereafter, using 

gas composition data measured during the preceding 12 months.

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 7 of 157

 (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)(910) 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 (109)

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 

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 (109)

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, 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 8 of 157

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. 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 9 of 157

 (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 

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 existing small glycol dehydration unit,

as defined in §63.761, located at a major source, that commenced 

construction before August 23, 2011, must achieve compliance no 

later than [INSERT DATE THREE YEARS AND 60 DAYS AFTER DATE OF 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 10 of 157

PUBLICATION IN THE FEDERAL REGISTER], except as provided in 

§63.6(i).

(8) Each affected new small glycol dehydration unit as,

defined in §63.761, located at a major source, that commenced 

construction on or after August 23, 2011, must achieve 

compliance immediately upon initial startup or [INSERT DATE 60 

DAYS AFTER DATE OF PUBLICATION IN THE FEDERAL REGISTER], 

whichever is later.

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

constructed on or before August 23, 2011 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 [INSERT THE DATE OF PUBLICATION IN THE FEDERAL 

REGISTER] must achieve compliance no later than [INSERT DATE 

THREE YEARS AND 60 DAYS AFTER DATE OF PUBLICATION 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). 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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 (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.[Reserved]

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 12 of 157

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 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 13 of 157

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.

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 14 of 157

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. 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 15 of 157

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. 

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, 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 16 of 157

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 

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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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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. 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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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 August 23, 2011. For the purposes of this 

subpart, for determining the percentage of overall HAP emission 

reduction attributable to process modifications, baseline 

operations shall be parameter 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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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 

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). A glycol 

dehydration unit complying with the 0.9 Mg/yr control option 

under §63.765(b)(1)(ii) is considered to be a large dehydrator.

 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; 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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 (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 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: 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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 (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, 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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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. 

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. 

 Responsible official means one of the following:

 (1) For a corporation: a president, secretary, treasurer, 

or vice-president of the corporation in charge of a principal 

business function, or any other person who performs similar 

policy or decision-making functions for the corporation, or a 

duly authorized representative of such person if the 

representative is responsible for the overall operation of one 

or more manufacturing, production, or operating facilities 

applying for or subject to a permit and either:

 (i) The facilities employ more than 250 persons or have 

gross annual sales or expenditures exceeding $25 million (in 

second quarter 1980 dollars); or
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 24 of 157

 (ii) The delegation of authority to such representatives is 

approved in advance by the permitting authority;

 (2) For a partnership or sole proprietorship: a general 

partner or the proprietor, respectively;

 (3) For a municipality, State, Federal, or other public 

agency: Either a principal executive officer or ranking elected 

official. For the purposes of this part, a principal executive 

officer of a Federal agency includes the chief executive officer 

having responsibility for the overall operations of a principal 

geographic unit of the agency (e.g., a Regional Administrator of 

EPA); or

 (4) For affected sources:

 (i) The designated representative in so far as actions, 

standards, requirements, or prohibitions under title IV of the 

Act or the regulations promulgated thereunder are concerned; and

 (ii) The designated representative for any other purposes 

under part 70.

 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 25 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 26 of 157

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

concrete, steel, plastic) that provide structural support. The 

following process units are not considered storage vessels: 

surge control vessels and knockout vessels. 

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. 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 27 of 157

Temperature monitoring device means an instrument used to 

monitor temperature and having a minimum accuracy of ±2 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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 28 of 157

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 mMalfunctions.Affirmative

defense for violations of emission standards during malfunction.

 (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 

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) [Reserved] 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 29 of 157

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 , shutdown, or malfunction of the affected source or a 

portion thereof.

 (c) [Reserved] 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, 

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 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. Backup 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 30 of 157

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 violations of such standards 

that are caused by malfunction, as defined at 40 CFR 63.2. 

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

meet your burden of proving all of the requirements in the 

affirmative defense, the affirmative defense shall not be 

available for claims for injunctive relief.

(1) To establish the affirmative defense in any action to 

enforce such a standard, you must timely meet the reporting
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 31 of 157

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

by a preponderance of evidence that:

(i) The violation:

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

failure of air pollution control equipment, process equipment, 

or a process to operate in a normal or usual manner; and 

(B) Could not have been prevented through careful planning, 

proper design or better operation and maintenance practices; and

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

been foreseen and avoided, or planned for; and 

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

inadequate design, operation, or maintenance; and 

(ii) Repairs were made as expeditiously as possible when a 

violation occurred. Off-shift and overtime labor were used, to 

the extent practicable to make these repairs; and 

(iii) The frequency, amount and duration of the violation 

(including any bypass) were minimized to the maximum extent 

practicable; and 

(iv) If the violation resulted from a bypass of control 

equipment or a process, then the bypass was unavoidable to 

prevent loss of life, personal injury, or severe property 

damage; and 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 32 of 157

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

the violation on ambient air quality, the environment, and human 

health; and 

(vi) All emissions monitoring and control systems were kept 

in operation if at all possible, consistent with safety and good 

air pollution control practices; and 

(vii) All of the actions in response to the violation were 

documented by properly signed, contemporaneous operating logs; 

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, the 

purpose of which is to determine, correct, and eliminate the 

primary causes of the malfunction and the violation resulting 

from the malfunction event at issue. The analysis shall also 

specify, using best monitoring methods and engineering judgment, 

the amount of any emissions that were the result of the 

malfunction.

(2) Report. The owner or operator seeking to assert an 

affirmative defense shall submit a written report to the 

Administrator with all necessary supporting documentation, that 

it has met the requirements set forth in paragraph (d)(1) of 

this section. This affirmative defense report shall be included 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 33 of 157

in the first periodic compliance, deviation report or excess 

emission report otherwise required after the initial occurrence 

of the violation of the relevant standard (which may be the end 

of any applicable averaging period). If such compliance, 

deviation report or excess emission report is due less than 45

days after the initial occurrence of the violation, the 

affirmative defense report may be included in the second 

compliance, deviation report or excess emission report due after 

the initial occurrence of the violation of the relevant 

standard.

§ 63.763 [Reserved] 

§ 63.764 General standards. 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 34 of 157

 (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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 35 of 157

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; 

 (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: 

 

 

 

 

 

 

 

 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 36 of 157

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 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 37 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 38 of 157

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 

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, 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 39 of 157

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.

§ 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 40 of 157

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). 

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

unit 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 existing

small glycol dehydration unit process vent, as defined in 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 41 of 157

§63.761, to the limit determined in Equation 1 of this section.

You must limit BTEX emissions from each new small glycol

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

limit determined in Equation 2 of this section. The limits 

determined using Equation 1 or Equation 2 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;

3.28x10-4= BTEX emission limit, grams BTEX/standard cubic meter 

-ppmv;

Throughput = Annual average daily natural gas throughput, 

standard cubic meters per day

Ci,BTEX = average annual BTEX concentration of the natural gas at 

the inlet to the glycol dehydration unit, ppmv.

 

 

 

 

 

 Equation 2

Where:

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

4.66x10-6 = 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 April 15, 2012 

Page 42 of 157

Ci,BTEX = average annual 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 April 15, 2012 

Page 43 of 157

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 

emissions to the atmosphere from the glycol dehydration unit 

process vent are reduced by one of the levels specified in 

paragraph (c)(3)(i) through or (ii)(iv) 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 any large glycol dehydration unit, bBenzene 

emissions are reduced to a level less than 0.90 megagrams per 

year.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 44 of 157

(iii) For each existing small glycol dehydration unit, BTEX 

emissions are reduced to a level less than the limit calculated 

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

 (iv) For each new small glycol dehydration unit, BTEX 

emissions are reduced to a level less than the limit calculated 

by Equation 2 of 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)through (3) of this section. 

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

vessel 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 45 of 157

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

paragraph (c) of this section.

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

connecting the cover, through a closed-vent system that meets 

the conditions specified in §63.771(c), to a process natural gas 

line.

 (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, subparts

Kb or OOOO; or is meeting is subject to and controlled under the 

requirements specified in 40 CFR part 63, subparts G or CC.

Storage vessels subject to and controlled under 40 CFR part 60, 

subpart OOOO shall submit the periodic reports specified in 

§63.775(e).

§§ 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 46 of 157

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 subject to and controlled under is 

meeting the requirements specified in 40 CFR part 60, subpart

OOOOKKK. Ancillary equipment and compressors subject to and 

controlled under 40 CFR part 60, subpart OOOO shall submit the 

periodic reports specified in §63.775(e).

 (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 §61.242-7(b) or 

§61.243-1, a leak is detected if an instrument reading of 500 

ppm or greater is measured. A leak detected from a valve at a 

source constructed on or before August 23, 2011 shall be 

repaired in accordance with the schedule in §61.242-7(d), or by 

[INSERT DATE 1 YEAR AND 60 DAYS AFTER THE DATE OF PUBLICATION IN 

THE FEDERAL REGISTER], whichever is later. A leak detected from 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 47 of 157

a valve at a source constructed on or after August 23, 2011 

shall be repaired in accordance with the schedule in §61.242-

7(d), or by [INSERT DATE 60 DAYS AFTER THE DATE OF PUBLICATION 

IN THE FEDERAL REGISTER], whichever is later.

 (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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 48 of 157

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.

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 49 of 157

 (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); 

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

 (iii) To inspect, maintain, repair, or replace equipment 

located inside the unit; or 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 50 of 157

 (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 

is capable of taking periodic readings and sounding an alarm 

when the bypass device is open such that the stream is being, or 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 51 of 157

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 

greater as determined in accordance with the requirements of 

§63.772(e); or 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 52 of 157

 (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) Operates at a minimum temperature of 760 degrees C, 

provided the control device has demonstrated, under §63.772(e),

that combustion zone temperature is an indicator of destruction

efficiency.Operates 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 April 15, 2012 

Page 53 of 157

 (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 April 15, 2012 

Page 54 of 157

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 April 15, 2012 

Page 55 of 157

 (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 April 15, 2012 

Page 56 of 157

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 April 15, 2012 

Page 57 of 157

§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 meet the levels 

specified in paragraphs (f)(1)(i)(A) or (B) of this section. If 

a boiler or process heater is used as the control device, then 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 58 of 157

the vent stream shall be introduced into the flame zone of the 

boiler or process heater.

 (A) The mass content of BTEX in the gases vented to the 

device is reduced as determined in accordance with the 

requirements of §63.772(e).

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

exhaust gases at the outlet of the device is reduced 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).

 (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).

 (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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 59 of 157

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 60 of 157

 (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: 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 61 of 157

 (b) Determination of glycol dehydration unit flowrate, 

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).

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 62 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 63 of 157

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: 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 64 of 157

inerts gases that 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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 65 of 157

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. 

 (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).
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 66 of 157

 (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.

 (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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 67 of 157

 (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 

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. Flares shall meet the provisions in paragraph 

(e)(2) of this section. 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); 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 68 of 157

 (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; 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 69 of 157

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 

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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 70 of 157

 (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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 71 of 157

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: 

 (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: 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 72 of 157

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. 

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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 73 of 157

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 GRI-GLYCalcTM , 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 GRIGLYCalcTM , 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. 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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(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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 75 of 157

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. 

 (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: 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 76 of 157

 (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. 

 (v) To determine compliance with the BTEX emission limit 

specified in §63.765(b)(1)(iii) 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 77 of 157

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.

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 

degrees 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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

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(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

(i.e., control devices installed on or before August 23, 2011)

at major sources shall be conducted no later than [INSERT DATE 3 

YEARS AFTER THE DATE OF PUBLICATION IN THE FEDERAL REGISTER]. If 

the owner or operator of an existing combustion control device 

at an 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 [INSERT DATE 3 YEARS AFTER THE DATE OF 

PUBLICATION 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 79 of 157

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) 

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 demonstrating during the 

performance test under §63.772(e) that combustion zone 

temperature is an indicator of destruction efficiency and 

operates at a minimum temperature of 760 degrees C.

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 80 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 81 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 82 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 83 of 157

(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 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) or 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 84 of 157

under the performance test conducted under §63.772(e), as 

applicable.

 (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, 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 85 of 157

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 86 of 157

 (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,

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 87 of 157

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 

(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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 88 of 157

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 

(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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 89 of 157

 (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).

 (ii) 70 - 100 - 70 percent (ramp up, ramp down). Begin the 

test at 70 percent of the maximum design rate. During the first 

5 minutes, incrementally ramp the firing rate to 100 percent of 

the maximum design rate. Hold at 100 percent for 5 minutes. In 

the 10-15 minute time range, incrementally ramp back down to 70 

percent of the maximum design rate. Repeat three more times for 

a total of 60 minutes of sampling.

 (iii) 30 - 70 - 30 percent (ramp up, ramp down). Begin the 

test at 30 percent of the maximum design rate. During the first 

5 minutes, incrementally ramp the firing rate to 70 percent of 

the maximum design rate. Hold at 70 percent for 5 minutes. In 

the 10-15 minute time range, incrementally ramp back down to 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. During the first 5 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 90 of 157

minutes, incrementally ramp the firing rate to 30 percent of the 

maximum design rate. Hold at 30 percent for 5 minutes. In the 

10-15 minute time range, incrementally ramp back down to 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 

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 

(h)(8)(iii) of this section.

 (4) Inlet gas testing shall be conducted as specified in 

paragraphs (h)(4)(i) through (iii) of this section.

 (i) The inlet gas flow metering system shall be located in 

accordance with Method 2A, 40 CFR part 60, appendix A-1, (or 

other approved procedure) to measure inlet gas flow rate at the 

control device inlet location. The fitting for filling inlet gas 

sample containers shall be located a minimum of 8 pipe diameters 

upstream of any inlet gas flow monitoring meter.

 (ii) Inlet gas flow rate shall be determined using Method 

2A, 40 CFR part 60, appendix A-1. Record the start and stop 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 91 of 157

reading for each 60-minute THC test. Record the inlet gas 

pressure and temperature at 5-minute intervals throughout each 

60-minute THC test.

 (iii) Inlet gas sampling shall be conducted in accordance 

with the criteria in paragraphs (h)(4)(iii)(A) and (B) of this 

section.

 (A) At the inlet gas sampling location, securely connect a 

Silonite-coated stainless steel evacuated canister fitted with a 

flow controller sufficient to fill the canister over a 3 hour 

period. 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 each THC test run.

 (2) Fill one canister across the three test runs for each 

THC test such that one composite fuel sample exists for each 

test conditionrun.

 (3) Label the canisters individually and record on a chain 

of custody form.

 (B) Each inlet gas 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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 92 of 157

 (2) Hydrogen (H2), carbon monoxide (CO), carbon dioxide 

(CO2), nitrogen (N2), oxygen (O2) using ASTM D1945-03.

 (3) 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:

 (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 or other pressure measurement device shall 

be used to obtain an accurate flow profile.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 93 of 157

 (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.

 (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 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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 94 of 157

 (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 

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.

 (v) Excess air shall be determined using resultant data 

from the EPA Method 3C tests and EPA Method 3B, 40 CFR part 60, 

Appendix A, equation 3B-1.

 (6) Total hydrocarbons (THC) shall be determined as 

specified by the following criteria:
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 95 of 157

 (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 each test.

 (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,” 

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:
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 96 of 157

 (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.

 (D) Excess combustion air shall be equal to or greater than 

150 percent.

 (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.

 (iii) A control device meeting the criteria in paragraphs

(h)(7)(i)(A) through (C) of this section will have demonstrated 

a destruction efficiency of 95.0 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 97 of 157

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 flowrate.

 (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.

(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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 98 of 157

(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: 

 (1) The inlet gas flow rate shall meet the range specified 

by the manufacturer. Flow rate shall be calculated 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).
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 99 of 157

 (3) Devices shall be operated with no visible emissions, 

except for periods not to exceed a total of 52 minutes during 

any hour. A visible emissions test using Method 22, 40 CFR part 

60, Appendix A, shall be performed each calendar quarter. The 

observation period shall be 21 hours and shall be conducted

according to EPA Method 22, 40 CFR part 60, Appendix A. 

 (4) Compliance with the operating parameter limit is 

achieved when the following criteria are met:

 (i) The inlet gas flow rate calculated 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 2 minutes during the 

observation period. Devices failing the visible emissions test 

shall follow manufacturers repair instructions, if available, or 

best combustion engineering practice as outlined in the unit 

inspection and maintenance plan, to return the unit to compliant 

operation. All repairs and maintenance activities for each unit 

shall be recorded in a maintenance and repair log and shall be 

available on site for inspection.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 100 of 157

 (iv) Following return to operation from maintenance or 

repair activity, each device must pass a Method 22 visual 

observation as described in paragraph (i)(3) 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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 101 of 157

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. 

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). 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 102 of 157

 (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. 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 103 of 157

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). 

 (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
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 104 of 157

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 105 of 157

 (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: 

 (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). 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 106 of 157

 (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 (97) 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 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 107 of 157

 (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;

 (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
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 108 of 157

 (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 (97) 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

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 109 of 157

 (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 ±2 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 ±2 percent of the 

temperature being monitored in °C, or ±2.5 °C, whichever value 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 110 of 157

 (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 

±2 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 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 exhaust vent stream from the condenser. 

 (F) For a regenerative-type carbon adsorption system: 

 (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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 111 of 157

completing the cooling cycle. The temperature monitoring device 

shall have a minimum accuracy of ±2 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 

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) The owner or operator shall determine actual average 

inlet waste gas flowrate using the model GRI-GLYCalcTM , Version 

3.0 or higher, ProMax, or AspenTech HYSYS. Inputs to the models

shall be representative of actual operating conditions of the 

controlled unit. The determination shall be performed to 

coincide with the visible emissions test under §63.772(i)(3);

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 112 of 157

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). 

 (4) Using the data recorded by the monitoring system, 

except for inlet gas flowrate, 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 113 of 157

 (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: 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 114 of 157

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 115 of 157

§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 

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)(vi) 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)(vi) 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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 116 of 157

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 

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(f)(1) 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 117 of 157

 (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. 

 (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 flowrate exceeds the maximum established 

during the test conducted under §63.772(h).

 (B) Failure of the quarterly 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 118 of 157

(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:

(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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 119 of 157

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 120 of 157

 (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 

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
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 121 of 157

 (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 

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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 122 of 157

 (C) For a 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 device

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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 123 of 157

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. 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 124 of 157

 (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. 

 (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: 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 125 of 157

 (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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 126 of 157

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);

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 127 of 157

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(aj), 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):

 (1) All visible emission readings and flowrate calculations

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 128 of 157

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 

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 [INSERT DATE ONE YEAR AFTER DATE OF PUBLICATION IN 

THE FEDERAL REGISTER], whichever is later. An affected source 

identified under §63.760(f)(7) or (9) that plans to be an area 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 129 of 157

source by [INSERT DATE 3 YEARS AFTER DATE OF PUBLICATION 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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 130 of 157

 (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. 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 131 of 157

 (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). 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 132 of 157

 (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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 133 of 157

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; 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 134 of 157

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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 135 of 157

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. 

 (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 unless the test 

results for that model of combustion control device are posted 

at the following website: epa.gov/airquality/oilandgas/. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 136 of 157

 (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. 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 137 of 157

 (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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 138 of 157

 (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 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 139 of 157

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).

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 140 of 157

 (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 

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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 141 of 157

(i) Name, address and telephone number of the control 

device manufacturer.

(ii) Control device model number.

(iii) Control device serial number.

(iv) Date the model of control device was tested by the 

manufacturer.

(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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 142 of 157

 (2) The owner or operator shall include the information 

specified in paragraphs (e)(2)(i) through (ix) 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 

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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 143 of 157

 (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 inlet gas flow rate

identified under §63.772(h) is exceeded, the report 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, repairs affected to the 

unit, and date the unit was returned to service. 

 (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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 144 of 157

 (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. 

 (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). 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 145 of 157

 (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).

 (ix) Certification by a responsible official of truth, 

accuracy, and completeness. This certification shall state that, 

based on information and belief formed after reasonable inquiry, 

the statements and information in the document are true, 

accurate, and complete. 

 (3) An owner or operator of an area source located inside a 

UA plus offset and UC boundary shall prepare and submit Periodic 

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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 146 of 157

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; 

 (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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 147 of 157

(g) Electronic Reporting. (1) Within 60 days after the date 

of completing each performance test(defined in §63.2) as 

required by this subpart you must submit the results of the 

performance tests required by this subpart to EPA’s WebFIRE 

database by using the Compliance and Emissions Data Reporting 

Interface (CEDRI) that is accessed through EPA’s Central Data 

Exchange (CDX)(www.epa.gov/cdx). Performance test data must be 

submitted in the file format generated through use of EPA’s 

Electronic Reporting Tool (ERT) (see 

http://www.epa.gov/ttn/chief/ert/index.html). Only data 

collected using test methods on the ERT website are subject to 

this requirement for submitting reports electronically to 

WebFIRE. Owners or operators who claim that some of the 

information being submitted for performance tests is 

confidential business information (CBI) must submit a complete 

ERT file including information claimed to be CBI on a compact 

disk or other commonly used electronic storage media (including, 

but not limited to, flash drives) to EPA. The electronic media 

must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE 

CBI Office, Attention: WebFIRE Administrator, MD C404-02, 4930 

Old Page Rd., Durham, NC 27703. The same ERT file with the CBI 

omitted must be submitted to EPA via CDX as described earlier in 

this paragraph. At the discretion of the delegated authority, 

you must also submit these reports, including the confidential 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 148 of 157

business information, to the delegated authority in the format 

specified by the delegated authority. 

(2) All reports required by this subpart not subject to 

the requirements in paragraph (g)(1) of this section must be 

sent to the Administrator at the appropriate address listed in 

§63.13. The Administrator or the delegated authority may request 

a report in any form suitable for the specific case (e.g., by 

commonly used electronic media such as Excel spreadsheet, on CD 

or hard copy). The Administrator retains the right to require 

submittal of reports subject to paragraph (g)(1) of this section 

in paper format.

§ 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. 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 149 of 157

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. 

 (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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 150 of 157

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]

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
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 151 of 157

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 

(a)(9)

No Section reserved.

§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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 152 of 157

§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.

§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 
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 153 of 157

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.

§63.6(g) Yes.

§63.6(h)(1) No. Subpart HH does not contain 

opacity or visible emission 

standards.

§63.6(h)(2) through 

(h)(9)

Yes.

§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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 154 of 157

§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) No.

§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.

§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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 155 of 157

§63.9(e) Yes.

§63.9(f) NoyYes. Subpart HH does not have opacity 

or visible emission standards.

§63.9(g)(1) Yes.

§63.9(g)(2) Noyes 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.

§63.10(b)(2) Yes.

§63.10(b)(2)(i) No.

§63.10(b)(2)(ii) No See §63.774(g) for recordkeeping 

of (1) occurrence and duration

and (2) 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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 156 of 157

§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 

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.
Proposed Subpart HH Redline/Strikeout April 15, 2012 

Page 157 of 157

§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.
Proposed Subpart HHH Redline/Strikeout April 15, 2012

Page 1 of 135

This document is not the official version of the proposed rule. Please refer 

to the CFR for the official version.

Subpart HHH-National Emission Standards for Hazardous Air 

Pollutants From Natural Gas Transmission and Storage Facilities 

§ 63.1270 Applicability and designation of affected source. 

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

gas transmission and storage facilities that transport or store 

natural gas prior to entering the pipeline to a local 

distribution company or to a final end user (if there is no 

local distribution company), and that are major sources of 

hazardous air pollutants (HAP) emissions as defined in §63.1271. 

Emissions for major source determination purposes can be 

estimated using the maximum natural gas throughput calculated in 

either paragraph (a)(1) or (2) of this section and paragraphs 

(a)(3) and (4) of this section. As an alternative to calculating 

the maximum natural gas throughput, the owner or operator of a 

new or existing source may use the facility design maximum 

natural gas 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 compressor station that transports natural gas 

prior to the point of custody transfer or to a natural gas 

processing plant (if present) is not considered a part of the 

natural gas transmission and storage source category. A facility 
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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 

limitations that keep its potential to emit HAP below major 

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

thereafter with all applicable provisions of this subpart 

starting on the applicable compliance date specified in 

paragraph (d) 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. 

 (1) Facilities that store natural gas or facilities that 

transport and store natural gas shall calculate maximum annual 

facility natural gas throughput using the following equation: 

 

 

 

 

 

 

 

 

 

Where: 

Throughput = Maximum annual facility wide natural gas throughput 

in cubic meters per year. 

IRmax = Maximum facility injection rate in cubic meters per hour. 

WRmax = Maximum facility withdrawal rate in cubic meters per 

hour. 

8,760 = Maximum hours of operation per year. 

 (i)–(iii) [Reserved] 

 (2) Facilities that only transport natural gas shall 

calculate the maximum natural gas throughput as the highest 
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annual natural gas throughput over the 5 years prior to June 17, 

1999, multiplied by a factor of 1.2. 

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

annual facility natural gas throughput each year and upon 

request, submit such records to the Administrator. If the 

facility annual natural gas throughput increases above the 

maximum natural gas throughput calculated in paragraph (a)(1) or 

(a)(2) of this section, the maximum natural gas throughput must 

be recalculated using the higher throughput multiplied by a 

factor of 1.2. 

 (4) The owner or operator shall determine the maximum 

values for other parameters used to calculate potential 

emissions as the maximum over the same period for which maximum 

throughput is determined as specified in paragraph (a)(1) or 

(a)(2) of this section. These parameters shall be based on an 

annual average or the highest single measured value. 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 and operational 

design consistent with the definition of potential to emit in 

§63.2.
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 (b) The affected source is each new and existing glycol 

dehydration unit .specified in paragraphs (b)(1) through (3) of 

this section.

 (1) Each large glycol dehydration unit;

 (2) Each small glycol dehydration unit for which 

construction commenced on or before August 23, 2011, is an 

existing small glycol dehydration unit.

 (3) Each small glycol dehydration unit for which 

construction commenced after August 23, 2011, is a new small 

glycol dehydration unit.

 (c) The owner or operator of a facility that does not 

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

this section, is not subject to the requirements of this 

subpart. 

 (d) The owner or operator of each affected source shall 

achieve compliance with the provisions of this subpart by the 

following dates: 

 (1) Except as specified in paragraphs (d)(3) through (4) of 

this section, tThe owner or operator of an affected source, the 

construction or reconstruction of which commenced before 

February 6, 1998, shall achieve compliance with this provisions 

of the subpart no later than June 17, 2002 except as provided 

for in §63.6(i). The owner or operator of an area source, the 
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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 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 paragraphs (d)(3) through (45) 

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

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 

June 17, 1999, whichever date is later. Area sources, 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) Each affected existing small glycol dehydration unit, 

as defined in §63.1271, located at a major source, that 

commenced construction before August 23, 2011, must achieve 

compliance no later than [INSERT DATE THREE YEARS AND 60 DAYS 

AFTER DATE OF PUBLICATION IN THE FEDERAL REGISTER], except as 

provided in §63.6(i).

 (4) Each affected new small glycol dehydration unit, as 

defined in §63.1271, located at a major source, that commenced 
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construction on or after August 23, 2011, must achieve 

compliance immediately upon initial startup or [INSERT DATE 60 

DAYS AFTER DATE OF PUBLICATION IN THE FEDERAL REGISTER], 

whichever is later.

 (e) 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 permitting requirements. 

 (f) Exemptions. A facility with a facility wide actual 

annual average natural gas throughput less than 28.3 thousand 

standard cubic meters per day, where glycol dehydration units 

are the only HAP emission source, is not subject to the 

requirements of this subpart. Records shall be maintained as 

required in §63.10(b)(3). 

§ 63.1271 Definitions. 

 All terms used in this subpart shall have the meaning given 

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

Provisions), and in this section. If the same term is defined in 

subpart A and in this section, it shall have the meaning given 

in this section for purposes of this subpart. 

 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 
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merits of which are independently and objectively evaluated in a 

judicial or administrative proceeding.

 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. 

BTEX means benzene, toluene, ethyl benzene and xylene.

 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. 

 Compressor station means any permanent combination of 

compressors that move natural gas at increased pressure from 

fields, in transmission pipelines, or into storage. 
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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 

absorbers, 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 a closed-vent system. 

Custody transfer means the transfer of natural gas after 

processing and/or treatment in the production operations to 

pipelines or any other forms of transportation. 

Facility means any grouping of equipment where natural gas 

is processed, compressed, or stored prior to entering a pipeline 

to a local distribution company or (if there is no local 

distribution company) to a final end user. Examples of a 

facility for this source category are: an underground natural 

gas storage operation; or a natural gas compressor station that 

receives natural gas via pipeline, from an underground natural 
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gas storage operation, or from a natural gas processing plant. 

The emission points associated with these phases include, but 

are not limited to, process vents. Processes that may have vents 

include, but are not limited to, dehydration and compressor 

station engines. 

 Facility, for the purpose of a major source determination, 

means natural gas transmission and storage equipment that is 

located inside the boundaries of an individual surface site (as 

defined in this section) and is connected by ancillary 

equipment, such as gas flow lines or power lines. Equipment that 

is part of a facility will typically be located within close 

proximity to other equipment located at the same facility. 

Natural gas transmission and storage equipment or groupings of 

equipment located on different gas leases, mineral fee tracts, 

lease tracts, subsurface unit areas, surface fee tracts, or 

surface lease tracts shall not be considered part of the same 

facility. 

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. 
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 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. 

 Gas-condensate-glycol (GCG) separator means a two-or threephase 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. 

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 dehydration 

unit operations as of August 23, 2011. For the purposes of this 

subpart, for determining the percentage of overall HAP emission 

reduction attributable to process modifications, glycol 
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dehydration unit baseline operations shall be parameter 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 (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. 

 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 
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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 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 

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 283.0 thousand standard cubic meters per day and 

actual annual average benzene emissions equal to or greater than 

0.90 Mg/yr, determined according to §63.1282(a). A glycol 

dehydration unit complying with the 0.9 Mg/yr control option 

under §63.1275(b)(1)(ii) is considered to be a large dehydrator.

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

meaning as in §63.2, except that: 
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 (1) Emissions from any pipeline compressor station or pump 

station shall not be aggregated with emissions from other 

similar units, whether or not such units are in a contiguous 

area or under common control; and 

 (2) Emissions from processes, operations, and equipment 

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

section, shall not be aggregated. 

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 transmission means the pipelines used for the 

long distance transport of natural gas (excluding processing). 

Specific equipment used in natural gas transmission includes the 

land, mains, valves, meters, boosters, regulators, storage 

vessels, dehydrators, compressors, and their driving units and 

appurtenances, and equipment used for transporting gas from a 

production plant, delivery point of purchased gas, gathering 

system, storage area, or other wholesale source of gas to one or 

more distribution area(s).

No detectable emissions means no escape of HAP from a 

device or system to the atmosphere as determined by: 
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 (1) Instrument monitoring results in accordance with the 

requirements of §63.1282(b); 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, 

over the appropriate averaging period as specified in §63.1282 

(e) and (f). 

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 
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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).

 Responsible official means one of the following:

 (1) For a corporation: a president, secretary, treasurer, 

or vice-president of the corporation in charge of a principal 

business function, or any other person who performs similar 

policy or decision-making functions for the corporation, or a 

duly authorized representative of such person if the 

representative is responsible for the overall operation of one 

or more manufacturing, production, or operating facilities 

applying for or subject to a permit and either:

 (i) The facilities employ more than 250 persons or have 

gross annual sales or expenditures exceeding $25 million (in 

second quarter 1980 dollars); or

 (ii) The delegation of authority to such representatives is 

approved in advance by the permitting authority;

 (2) For a partnership or sole proprietorship: a general 

partner or the proprietor, respectively;

 (3) For a municipality, State, Federal, or other public 

agency: Either a principal executive officer or ranking elected 

official. For the purposes of this part, a principal executive 

officer of a Federal agency includes the chief executive officer 
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having responsibility for the overall operations of a principal 

geographic unit of the agency (e.g., a Regional Administrator of 

EPA); or

 (4) For affected sources:

 (i) The designated representative in so far as actions, 

standards, requirements, or prohibitions under title IV of the 

Act or the regulations promulgated thereunder are concerned; and

 (ii) The designated representative for any other purposes 

under part 70.

Safety device means a device that meets both of the 

following conditions: the device 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 the device 

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. 
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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 283.0 thousand standard cubic 

meters per day or actual annual average benzene emissions less 

than 0.90 Mg/yr, determined according to §63.1282(a).

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, produced water, or other 

liquid, and is constructed primarily of non-earthen materials 

(e.g., wood, concrete, steel, plastic) that provide structural 

support. 

Surface site means any combination of one or more graded 

pad sites, gravel pad sites, foundations, platforms, or the 
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immediate physical location upon which equipment is physically 

affixed. 

Temperature monitoring device means an instrument used to 

monitor temperature and having a minimum accuracy of ±2 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. 

Underground storage means the subsurface facilities 

utilized for storing natural gas that has been transferred from 

its original location for the primary purpose of load balancing, 

which is the process of equalizing the receipt and delivery of 

natural gas. Processes and operations that may be located at an 

underground storage facility include, but are not limited to, 

compression and dehydration. 

§ 63.1272 Affirmative defense for violations of emission 

standards during malfunction.Startups, shutdowns, and 

malfunctions.

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

all times times except during startups or shutdowns, during 
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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 

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) [Reserved]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) [Reserved]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 
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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 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, or 

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 the startup, shutdown, or malfunction 

does not shield an owner or operator from enforcement actions.

(e) Owners or operators are exempt from the requirements to 

prepare a startup, shutdown, or malfunction plan for any 
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facility where all of the affected sources meet the exemption 

criteria specified in §63.1274(d).

 (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 violations of such standards 

that are caused by malfunction, as defined at 40 CFR 63.2. 

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

meet your burden of proving all of the requirements in the 

affirmative defense, the affirmative defense shall not be 

available for claims for injunctive relief.

 (1) To establish the affirmative defense in any action to 

enforce such a standard, you must timely meet the reporting

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

by a preponderance of evidence that:

 (i) The violation:

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

failure of air pollution control equipment, process equipment, 

or a process to operate in a normal or usual manner; and 

 (B) Could not have been prevented through careful planning, 

proper design or better operation and maintenance practices; and

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

been foreseen and avoided, or planned for; and 
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 (D) Was not part of a recurring pattern indicative of 

inadequate design, operation, or maintenance; and 

 (ii) Repairs were made as expeditiously as possible when a 

violation occurred. Off-shift and overtime labor were used, to 

the extent practicable to make these repairs; and 

 (iii) The frequency, amount and duration of the violation 

(including any bypass) were minimized to the maximum extent 

practicable; and 

 (iv) If the violation resulted from a bypass of control 

equipment or a process, then the bypass was unavoidable to 

prevent loss of life, personal injury, or severe property 

damage; and 

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

the violation on ambient air quality, the environment, and human 

health; and 

 (vi) All emissions monitoring and control systems were kept 

in operation if at all possible, consistent with safety and good 

air pollution control practices; and 

 (vii) All of the actions in response to the violation were 

documented by properly signed, contemporaneous operating logs; 

and 
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 (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, the 

purpose of which is to determine, correct, and eliminate the 

primary causes of the malfunction and the violation resulting 

from the malfunction event at issue. The analysis shall also 

specify, using best monitoring methods and engineering judgment, 

the amount of any emissions that were the result of the 

malfunction.

 (2) Report. The owner or operator seeking to assert an 

affirmative defense shall submit a written report to the 

Administrator with all necessary supporting documentation, that 

it has met the requirements set forth in paragraph (d)(1) of 

this section. This affirmative defense report shall be included 

in the first periodic compliance, deviation report or excess 

emission report otherwise required after the initial occurrence 

of the violation of the relevant standard (which may be the end 

of any applicable averaging period). If such compliance, 

deviation report or excess emission report is due less than 45 

days after the initial occurrence of the violation, the 

affirmative defense report may be included in the second 

compliance, deviation report or excess emission report due after 
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the initial occurrence of the violation of the relevant 

standard.

§ 63.1273 [Reserved] 

§ 63.1274 General standards. 

 (a) Table 2 of this subpart specifies the provisions of 

subpart A (General Provisions) 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 (d) of this section, 

Tthe owner or operator of an affected source (i.e., glycol 

dehydration unit) located at an existing or new major source of 

HAP emissions shall comply with the requirements in this subpart 

as follows: 

 (1) The control requirements for glycol dehydration unit 

process vents specified in §63.1275; 

 (2) The monitoring requirements specified in §63.1283, and 

 (3) The recordkeeping and reporting requirements specified 

in §§63.1284 and 63.1285.

 (d) [Reserved] Exemptions. The owner or operator is exempt 

from the requirements of paragraph (c) of this section if the 
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criteria listed in paragraph (d)(1) or (2) of this section are 

met, except that the records of the determination of these 

criteria must be maintained as required in §63.1284(d).

(1) The actual annual average flow of gas to the glycol 

dehydration unit is less than 283.0 thousand standard cubic 

meters per day, as determined by the procedures specified in 

§63.1282(a)(1); or

(2) The actual average emissions of benzene from the glycol 

dehydration unit process vents to the atmosphere are less than 

0.90 megagram per year as determined by the procedures specified 

in §63.1282(a)(2) of this subpart.

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

this subpart is required to apply for a part 70 or part 71 

operating permit from the appropriate permitting authority. If 

the Administrator has approved a State operating permit program 

under part 70, the permit shall be obtained from the State 

authority. If a State operating permit program has not been 

approved, the owner or operator shall apply to the EPA Regional 

Office pursuant to part 71. 

 (f) [Reserved] 

 (g) 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 
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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.

 (h) 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.

§ 63.1275 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 283.0 thousand standard 

cubic meters per day and with actual average benzene glycol 

dehydration unit process vent emissions equal to or greater than 
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0.90 megagrams per year that must be controlled for air

emissions as specified in paragraph (c)(1) of §63.1274.

 (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)(iii) of this section. 

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

unit, as defined in §63.1271, 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 §63.1281(c). The 

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

with the requirements of §63.1281(d). 

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

unit shall connect the process vent to a control device or a 

combination of control devices through a closed-vent system and 

the outlet benzene emissions from the control device(s) shall be 

less than 0.90 megagrams per year. The closed-vent system shall 

be designed and operated in accordance with the requirements of 

§63.1281(c). The control device(s) shall be designed and 
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operated in accordance with the requirements of §63.1281(d), 

except that the performance requirements specified in 

§63.1281(d)(1)(i) and (ii) do not apply.

 (iii) You must limit BTEX emissions from each existing

small glycol dehydration unit, as defined in §63.1271, to the 

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

BTEX emissions from each new small glycol dehydration unit 

process vent, as defined in §63.1271, to the limit determined in 

Equation 2 of this section. The limits determined using Equation 

1 or Equation 2, of this section, 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;

3.10x10-4 = BTEX emission limit, grams BTEX/standard cubic meter 

-ppmv;

Throughput = Annual average daily natural gas throughput, 

standard cubic meters per day

Ci,BTEX = Annual average BTEX concentration of the natural gas at 

the inlet to the glycol dehydration unit, ppmv.

 

 

 

 

 

 Equation 2

Where:

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

5.44x10-5 = BTEX emission limit, grams BTEX/standard cubic meter 

-ppmv;

Throughput = Annual average daily natural gas throughput, 

standard cubic meters per day
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Ci,BTEX = Annual average 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 §63.1281(c). The control 

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

requirements of §63.1281(f).

 (B) Meet the emissions limit through process modifications 

in accordance with the requirements specified in §63.1281(e).

 (C) Meet the emission 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 §63.1281(e) and emissions in 

accordance with the requirements specified in §63.1282(a)(3).

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

of this section, the owner or operator may comply with one of 

the following: 

 (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 §63.1281(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 

emissions to the atmosphere from the glycol dehydration unit 

process vent are reduced by one of the levels specified in 

paragraph (c)(3)(i) through or (iiiv) 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. 
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 (ii) For any large glycol dehydration unit, bBenzene 

emissions are reduced to a level less than 0.90 megagrams per 

year.

 (iii) For each existing small glycol dehydration unit, BTEX 

emissions are reduced to a level less than the limit calculated 

in Equation 1 of paragraph (b)(1)(iii) of this section.

 (iv) For each new small glycol dehydration unit, BTEX 

emissions are reduced to a level less than the limit calculated 

in Equation 2 of paragraph (b)(1)(iii) of this section.

§§ 63.1276-63.1280 [Reserved] 

§ 63.1281 Control equipment requirements. 

 (a) This section applies to each 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 (c) and (d) of this section 

will be determined by review of the records required by 

§63.1284, the reports required by §63.1285, by review of 

performance test results, and by inspections. 

 (b) [Reserved] 

 (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. 
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 (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 

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. 
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 (d) Control device requirements for sources except small 

glycol dehydration units. Owners and operators of small glycol 

dehydration units shall comply with the control 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 

greater, as determined in accordance with the requirements of 

§63.1282(d); 

 (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 §63.1282(d); or 

 (C) Operates at a minimum residence time of 0.5 second at a 

minimum temperature of 760 °C, provided the control device has 
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demonstrated, under §63.1282(d), that combustion zone 

temperature is an indicator of destruction efficiency.

 (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 §63.1282(d). 

 (iii) A flare, as defined in §63.1271, that is designed and 

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

 (2) [Reserved] 

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

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

of this section by following the procedures specified in 

§63.1282(d). 

 (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 
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are vented from the emissions unit or units through the closedvent system to the control device, as required under §63.1275, 

except when maintenance or repair of 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 §63.1283(d), the owner or operator shall 

demonstrate compliance according to the requirements of 

§63.1282(e), or (f) 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 

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 §63.1284(b)(7)(ix). The schedule for 

replacement shall be submitted with the Notification of 

Compliance Status Report as specified in §63.1285(d)(4)(iv). 
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Each carbon replacement must be reported in the Periodic Reports 

as specified in §63.1285(e)(2)(xi).

 (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 organic 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. 

 (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. 
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 (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 §63.1275(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 §63.1271). 

Records of glycol dehydration unit baseline operations shall be 

retained as required under §63.1284(b)(9). 

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

Administrator's satisfaction, the conditions for which glycol 

dehydration unit baseline operations shall be modified to 

achieve the 95.0 percent overall HAP emission reduction, or BTEX 

limit determined in §63.1275(b)(1)(iii), as applicable, either 
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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 HAP emission 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 §63.1275(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 

§63.1275(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

§63.1275(b)(1)(iii), as applicable, using a combination of 
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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 §63.1284(b)(10), 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 §63.1275(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 meet the levels 

specified in paragraphs (f)(1)(i)(A) or (B) of this section. If 

a boiler or process heater is used as the control device, then 
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the vent stream shall be introduced into the flame zone of the 

boiler or process heater.

 (A) The mass content of BTEX in the gases vented to the 

device is reduced as determined in accordance with the 

requirements of §63.1282(d).

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

exhaust gases at the outlet of the device is reduced 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 §63.1282(e). (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 

§63.1282(d).

 (iii) A flare, as defined in §63.1271, 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 
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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 §63.1283(d), the owner or operator shall 

demonstrate compliance according to the requirements of either 

§63.1282(e) or (h).

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

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

section, the owner or operator shall manage the carbon as 

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

§ 63.1282 Test methods, compliance procedures, and compliance 

demonstrations. 

 (a) 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 the

exemption from control requirements under §63.1274(d).

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

a glycol dehydration unit shall be made using the procedures of 

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

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

monitoring instrument that directly measures natural gas 
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flowrate to the glycol dehydration unit with an accuracy of plus 

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

convert the 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 

283.0 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 (a)(2)(i) or (a)(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 

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

rate of benzene or BTEX emissions in kilograms per hour through 

direct measurement by performing three runs of Method 18 in 40 

CFR part 60, appendix A; or ASTM D6420-99(2004), as specified in 

§63.772(a)(1)(ii); (or an equivalent method);, and averaging the 

results of the three runs. 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.

 (b) No detectable emissions test procedure. (1) The 

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 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: 

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

hydrocarbon in air); and 
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 (ii) A mixture of methane in air at a methane concentration 

of 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 (b)(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 gases that which are not organic HAP or VOC, 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 

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

adjusted by multiplying by the average response factor of the 
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process fluid, calculated on an inert-free basis as described in 

paragraph (b)(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 (b)(7)(i) or 

(b)(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 (b)(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 (b)(5) of this section is compared with 

the applicable value for the potential leak interface as 

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

 (8) A potential leak interface is determined to operate 

with no detectable organic emissions if the organic 
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concentration value determined in paragraph (b)(7) is less than 

500 parts per million by volume. 

 (c) [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 §63.1275(b)(1)(iii), the 

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

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

this section.

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

emission limit in §63.1275(b)(1)(iii), the owner or operator 

must determine the glycol dehydration unit BTEX emissions as 

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

Compliance is demonstrated if the BTEX emissions determined as 

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

the emission limit calculated using the equation in 

§63.1275(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 
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references to particulate mentioned in Methods 1 and 1A do not 

apply to this section.

 (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 (d)(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.

 (d) 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 
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achieves the performance requirements of §63.1281(d)(1), or 

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

specified in paragraph (d)(3) of this section. Owners or 

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

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

owner or operator may elect to use the alternative procedures in 

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

condenser used to control emissions from a glycol dehydration 

unit process vent. Flares shall meet the provisions in paragraph 

(d)(2) of this section. 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 §63.1281(d)(1), (e)(3)(ii) or (f)(1) 

through a performance test conducted by the manufacturer, as 

specified in paragraph (g) 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 (d)(2) of this 

section, a flare, as defined in §63.1271, that is designed and 

operated in accordance with §63.11(b); 
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 (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; 

 (iv) Except for control devices used for small glycol 

dehydration units, aA 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, a A 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 
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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 §63.1271, in accordance with the 

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

and (d)(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 concentration when a flare is used.

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

control device meets the requirements of §63.1281(d)(1), or

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

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

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

submitted in the Notification of Compliance Status Report as 

required in §63.1285(d)(1)(ii). The initial and periodic 
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performance tests shall be conducted according to the schedule 

specified in paragraph (d)(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 

specified in paragraphs (d)(3)(i)(A) and (B) of this section. 

Any references to particulate mentioned in Methods 1 and 1A do 

not apply to this section. 

 (A) To determine compliance with the control device percent 

reduction requirements specified in 

§63.1281(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 

§63.1281(d)(1)(i)(B), or the BTEX emission limit specified in 

§63.1275(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 

§63.1281(d)(1)(i)(A), 63.1281(d)(1)(ii), or 63.1281(e)(3)(ii), 
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the owner or operator shall use either 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);

alternatively, any other method or data that have been validated 

according to the applicable procedures in Method 301 of appendix 

A of this part may be used. The following procedures shall be 

used to calculate the percentage of reduction: 

 (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 (d)(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 (d)(3)(iii)(B)(4) of this section.

 (1) The following equations shall be used: 

 

 

 
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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. 

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)−1(gram-mole per 

standard cubic meter) (kilogram/gram) (minute/hour), where 

standard temperature 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, of 

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

appendix A, shall be summed using the equations in paragraph 

(d)(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 (d)(3)(iii)(B)(1) of this 

section. 

 (4) As an alternative to the procedures for calculating 

Eispecified in paragraph (d)(3)(iii)(B)(1) of this section, the 

owner or operator may use the model GRI-GLYCalcTM , Version 3.0 
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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 GRI-GLYCalcTM , 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 GRIGLYCalcTM , only HAP chemicals listed in Table 1 of this subpart 

shall be summed. 

 (C) The percentage of reduction in TOC (minus methane and 

ethane) or total HAP shall be calculated as follows: 

 

 

 

 

Where: 

Rcd= Control efficiency of control device, percent. 

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

the inlet to the control device as calculated under paragraph 

(d)(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 

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

kilograms HAP per hour. 
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 (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-percentage 

of 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 

§63.1281(d)(1)(i)(B), the owner or operator shall use either 

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), to measure either TOC (minus methane and 

ethane) or total HAP. Alternatively, any other method or data 

that have been validated according to Method 301 of appendix A 

of this part, may be used. 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 
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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 (d)(3)(iv)(B)(1) or 

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

 (1) The TOC concentration (CTOC) 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 components 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. 

 (2) The total HAP concentration (CHAP) shall be computed 

according to the equation in paragraph (d)(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 
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oxygen concentration (%O2d). The samples shall be taken during 

the same time that the samples are taken for determining TOC 

concentration or total HAP concentration. 

 (2) The concentration corrected to 3 percent oxygen (Cc) 

shall be computed using the following equation: 

 

 

 

 

Where: 

Cc= TOC concentration of 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. 

 (v) To determine compliance with the BTEX emission limit 

specified in §63.1275(b)(1)(iii) 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)(i); 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.
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 (B) The mass rate of BTEX (Eo) shall be computed using the 

equations and procedures specified in paragraphs (d)(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.

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 (d)(3)(v)(B)(1) of 

this section.

 (vi) The owner or operator shall conduct performance tests 

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

and (B) of this section.
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 (A) An initial performance test shall be conducted within 

180 days after the compliance date that is specified for each 

affected source in §63.1270(d)(3) and (4) except that the 

initial performance test for existing combustion control devices 

(i.e., control devices installed on or before August 23, 2011) 

at major sources shall be conducted no later than [INSERT DATE 

THREE YEARS AFTER DATE OF PUBLICATION IN THE FEDERAL REGISTER]. 

If the owner or operator of an existing combustion control 

device at an major source chooses to replace such device with a 

control device whose model is tested under §63.1282(g), then the 

newly installed device shall comply with all provisions of this 

subpart no later than [INSERT DATE THREE YEARS AFTER DATE OF 

PUBLICATION IN THE FEDERAL REGISTER]. The performance test 

results shall be submitted in the Notification of Compliance 

Status Report as required in §63.1285(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 (d)(3)(vi)(A) of this section. 

Subsequent periodic performance tests shall be conducted at 

intervals no longer than 60 months following the previous 
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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 §63.1285(e)(2)(x). Combustion control devices 

meeting the criteria in either paragraph (e)(3)(vi)(B)(1) or (2) 

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, §63.1282(g), or

 (2) A combustion control device demonstrating during the 

performance test under §63.1282(d) that combustion zone 

temperature is an indicator of destruction efficiency and 

operates at a minimum temperature of 760 degrees C.

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

requirements of §63.1281(d)(1), or (e)(3)(ii), or (f)(1), the 

owner or operator shall meet the requirements specified in 

paragraphs (d)(4)(i) and (d)(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 §63.1285(d)(1)(i). 

 (i) The condenser design analysis shall include an analysis 

of the vent stream characteristics and control device operating 
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parameters for the applicable control device as specified in 

paragraphs (d)(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 

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 of 

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 
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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 (d)(5) of this section. 

(E) For a regenerable carbon adsorption, 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, 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 
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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 

operator in accordance with the requirements of paragraph (d)(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

(d)(3) and (d)(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.

 (e) Compliance demonstration for control devices 

performance requirements. This paragraph applies to the 

demonstration of compliance with the control device performance 

requirements specified in §63.1281(d)(1), and (e)(3)(ii), and 

(f)(1). Compliance shall be demonstrated using the requirements 

in paragraphs (e)(1) through (3) of this section. As an 
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alternative, an owner or operator that installs a condenser as 

the control device to achieve the requirements specified in 

§63.1281(d)(1)(ii), or (e)(3)(ii), or (f)(1) may demonstrate 

compliance according to paragraph (f) of this section. An owner 

or operator may switch between compliance with paragraph (e) of 

this section and compliance with paragraph (f) of this section 

only after at least 1 year of operation in compliance with the 

selected approach. Notification of such a change in the 

compliance method shall be reported in the next Periodic Report, 

as required in §63.1285(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 §63.1283(d)(5)(i). 

 (2) The owner or operator shall calculate the daily average 

of the applicable monitored parameter in accordance with 

§63.1283(d)(4) except that the inlet gas flowrate to the control 

device shall not be averaged.

 (3) Compliance is achieved when the daily average of the 

monitoring parameter value calculated under paragraph (e)(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 (e)(1) of this section. For inlet gas flowrate, 

compliance with the operating parameter limit is achieved when 
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the value is equal to or less than the value established under 

§63.1282(g) or under the performance test conducted under 

§63.1282(d), as applicable.

 (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 

§63.1283(d) must be operated at all times the affected source is 

operating. A monitoring system malfunction is any sudden, 

infrequent, not reasonably preventable failure of the monitoring 

system to provide valid data. Monitoring system failures that 

are caused in 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 
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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.

 (f) Compliance demonstration with percent reduction or 

emission limit performance requirements—condensers. This 

paragraph applies to the demonstration of compliance with the 

performance requirements specified in §63.1281(d)(1)(ii), (e)(3) 

or (f)(1) for condensers. Compliance shall be demonstrated using 

the procedures in paragraphs (f)(1) through (f)(3) of this 

section.

 (1) The owner or operator shall establish a site-specific 

condenser performance curve according to the procedures 

specified in §63.1283(d)(5)(ii). For sources required to meet 

the BTEX limit in accordance with §63.1281(e) or (f)(1) the 

owner or operator shall identify the minimum percent reduction 

necessary to meet the BTEX limit.
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 (2) Compliance with the percent reduction requirement in 

§63.1281(d)(1)(ii), or (e)(3), or (f)(1) shall be demonstrated 

by the procedures in paragraphs (f)(2)(i) through (iii) of this 

section. 

 (i) The owner or operator must calculate the daily average 

condenser outlet temperature in accordance with §63.1283(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 in paragraph (f)(2)(i) 

of this section and the condenser performance curve established 

in paragraph (f)(1) of this section. 

 (iii) Except as provided in paragraphs (f)(2)(iii)(A), (B), 

and (D) of this section, at the end of each operating day the 

owner or operator shall calculate the 30-day average HAP, or 

BTEX, emission reduction, as appropriate, from the condenser 

efficiencies as determined in paragraph (f)(2)(ii) of this 

section for the preceding 30 operating days. If the owner or 

operator uses a combination of process modifications and a 

condenser in accordance with the requirements of §63.1281(e), 

the 30-day average HAP emission, or BTEX, emission reduction 

shall be calculated using the emission reduction achieved 

through process modifications and the condenser efficiency as 
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determined in paragraph (f)(2)(ii) of this section, both for the 

preceding 30 operating days. 

 (A) After the compliance date specified in §63.1270(d), an 

owner or operator of a facility that stores natural gas that has 

less than 30 days of data for determining the average HAP, or 

BTEX, emission reduction, as appropriate, shall calculate the 

cumulative average at the end of the withdrawal season, each 

season, until 30 days of condenser operating data are 

accumulated. For a facility that does not store natural gas, the 

owner or operator that has less than 30 days of data for 

determining average HAP, or BTEX, emission reduction, as 

appropriate, shall calculate the cumulative average at the end 

of the calendar year, each year, until 30 days of condenser 

operating data are accumulated. 

 (B) After the compliance date specified in §63.1270(d), for 

an owner or operator that has less than 30 days of data for 

determining the average HAP, or BTEX, emission reduction, as 

appropriate, compliance is achieved if the average HAP, or BTEX,

emission reduction, as appropriate, calculated in paragraph 

(f)(2)(iii)(A) of this section is equal to or greater than 95.0 

percent or is equal to or greater than the minimum percent 

reduction necessary to meet the BTEX emission limit as 

determined in paragraph (f)(1) of this section.
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 (C) For the purposes of this subpart, a withdrawal season 

begins the first time gas is withdrawn from the storage field 

after July 1 of the calendar year and ends on June 30 of the 

next calendar year. 

 (D) Glycol dehydration units that are operated continuously 

have the option of complying with the requirements specified in 

40 CFR 63.772(g). 

 (3) Compliance is achieved based on the applicable criteria 

in paragraphs (f)(3)(i) or (ii) of this section.

 (i) For sources meeting the HAP with the emission 

limitation specified in §63.1281(d)(1)(ii) or (e)(3) if the 

average HAP emission reduction specified in §63.1281(d)(1)(ii) 

or (e)(3) if the average HAP emission reduction calculated in 

paragraph (f)(2)(iii) of this section is equal to or greater 

than 95.0 percent.

 (ii) For sources required to meet the BTEX limit under 

§63.1281(e)(3) or (f)(1), compliance is achieved if the average 

BTEX emission reduction calculated in paragraph (f)(2)(iii) of 

this section is equal to or greater than the minimum percent 

reduction identified in paragraph (f)(1) of this section.

(g) Performance testing for combustion control devices -

manufacturers’ performance test. 
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 (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 (g)(7) 

of this section by conducting a performance test as specified in 

paragraphs (g)(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).

 (ii) 70 - 100 - 70 percent (ramp up, ramp down). Begin the 

test at 70 percent of the maximum design rate. WithinDuring the 

first 5 minutes, incrementally ramp the firing rate to 100 

percent of the maximum design rate. Hold at 100 percent for 5 

minutes. In the 10-15 minute time range, incrementally ramp back 

down to 70 percent of the maximum design rate. Repeat three more 

times for a total of 60 minutes of sampling.

 (iii) 30 - 70 - 30 percent (ramp up, ramp down). Begin the 

test at 30 percent of the maximum design rate. Within During the 
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first 5 minutes, incrementally ramp the firing rate to 70 

percent of the maximum design rate. Hold at 70 percent for 5 

minutes. In the 10-15 minute time range, incrementally ramp back 

down to 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. DuringWithin the 

first 5 minutes, incrementally ramp the firing rate to 10030

percent of the maximum design rate. Hold at 30 percent for 5 

minutes. In the 10-15 minute time range, incrementally ramp back 

down to 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 

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 

(g)(8)(iii) of this section.

 (4) Inlet testing shall be conducted as specified in 

paragraphs (g)(4)(i) through (iii) of this section.
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 (i) The inlet gas flow metering system shall be located in 

accordance with Method 2A, 40 CFR part 60, appendix A-1, (or 

other approved procedure) to measure inlet gas flow rate at the 

control device inlet location. The fitting for filling inlet gas

sample containers shall be located a minimum of 8 pipe diameters 

upstream of any inlet gas flow monitoring meter.

 (ii) Inlet gas 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 inlet gas 

pressure and temperature at 5-minute intervals throughout each 

60-minute THC test.

 (iii) Inlet gas sampling shall be conducted in accordance 

with the criteria in paragraphs (g)(4)(iii)(A) and (B) of this 

section.

 (A) At the inlet gas sampling location, securely connect a 

Silonite-coated stainless steel evacuated canister fitted with a 

flow controller sufficient to fill the canister over a 3 hour 

period. 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 each THC test run.
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 (2) Fill one canister across the three test runs for each 

THC test such that one composite fuel sample exists for each 

test condition.

 (3) Label the canisters individually and record on a chain 

of custody form.

 (B) Each inlet gas 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) Higher heating value using ASTM D3588-98 or ASTM D4891-

89.

 (5) Outlet testing shall be conducted in accordance with 

the criteria in paragraphs (g)(5)(i) through (v) of this 

section.

 (i) Sampling and flowrate measured in accordance with the 

following:

 (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 
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equivalent stack diameter upstream of the exit or any other flow 

disturbance. A minimum of two sample ports shall be used. 

 (B) Flowrate 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 or other pressure measurement device shall 

be used to obtain an accurate flow profile.

 (ii) Molecular weight shall be determined as specified in 

paragraphs (g)(4)(iii)(B), and (g)(5)(ii)(A) and (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.

 (2) The sampling line shall be purged with stack gas before 

opening the valve and beginning to fill the bag.
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 (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 EPAAlt-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.

 (v) Excess air shall be determined using resultant data 

from the EPA Method 3C tests and EPA Method 3B, 40 CFR part 60, 

Appendix A, equation 3B-1.

 (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 run.

 (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.
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 (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,” 

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 (g)(7)(i)(A) through (C) of this section:

 (A) Method 22, 40 CFR part 60, Appendix A, results under 

paragraph (g)(5)(iv) of this section with no indication of 

visible emissions, and

 (B) Average Method 25A, 40 CFR part 60, Appendix A, 

results under paragraph (g)(6) of this section equal to or less 

than 10.0 ppmvw THC as propane corrected to 3.0 percent CO2, and 
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 (C) Average CO emissions determined under paragraph 

(g)(5)(iii) of this section equal to or less than 10 parts 

ppmvd, corrected to 3.0 percent CO2.

 (D) Excess combustion air shall be equal to or greater than 

150 percent. 

 (ii) The manufacturer shall determine a maximum inlet gas 

flowrate which shall not be exceeded for each control device 

model to achieve the criteria in paragraph (g)(7)(i) of this 

section.

 (iii) A control device meeting the criteria in paragraph 

(g)(7)(i)(A) through (C) of this section will have demonstrated 

a destruction efficiency of 95.0 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 (g)(8)(i) through (iii) 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 flowrate.
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 (iv) Air/stream injection/assist ranges, if used.

 (v) The test parameter ranges listed in paragraphs 

(g)(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.

(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 flowrate.

 (O) Wind velocity and direction.

 (vi) The test report shall include all calibration quality 

assurance/quality control data, calibration gas values, gas 
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cylinder certification, and strip charts annotated with test 

times and calibration values. 

 (h) 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 (g) of this section. 

Owners or operators shall demonstrate that a control device 

achieves the performance requirements of §63.1281(d)(1), 

(e)(3)(ii) or (f)(1), by installing a device tested under 

paragraph (g) of this section and complying with the following 

criteria: 

 (1) The inlet gas flowrate shall meet the range specified 

by the manufacturer. Flowrate shall be calculated as specified 

in §63.1283(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 

§63.1283(d)(3)(i)(H)(2).

 (3) Devices shall be operated with no visible emissions, 

except for periods not to exceed a total of 2 minutes during any 

hour. A visible emissions test using Method 22, 40 CFR part 60, 

Appendix A, shall be performed each calendar quarter. The 

observation period shall be 1 hour and shall be conducted

according to EPA Method 22, 40 CFR part 60, Appendix A. 
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 (4) Compliance with the operating parameter limit is 

achieved when the following criteria are met:

 (i) The inlet gas flowrate monitored under paragraph (h)(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 (h)(3) of this section the duration of visible 

emissions does not exceed a total of 2 minutes during the 

observation period. Devices failing the visible emissions test 

shall follow manufacturers repair instructions, if available, or 

best combustion engineering practice as outlined in the unit 

inspection and maintenance plan, to return the unit to compliant 

operation. All repairs and maintenance activities for each unit 

shall be recorded in a maintenance and repair log and shall be 

available on site for inspection.
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 (iv) Following return to operation from maintenance or 

repair activity, each device must pass a Method 22 visual

observation as described in paragraph (h)(3) of this section.

§ 63.1283 Inspection and monitoring requirements. 

 (a) This section applies to an owner or operator using air 

emission controls in accordance with the requirements of 

§63.1275. 

 (b) The owner or operator of a control device whose model 

was tested under 63.1282(g) 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) Closed-vent system inspection and monitoring 

requirements. (1) For each closed-vent system required to comply 

with this section, the owner or operator shall comply 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 and each bypass device shall be 
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inspected according to the procedures of (c)(2)(iii) 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 or gasketed ducting flange), the owner or operator shall: 

 (A) Conduct an initial inspection according to the 

procedures specified in §63.1282(b) 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 §63.1285(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. 

The owner or operator shall monitor a component or connection 

using the procedures specified in §63.1282(b) to demonstrate 

that it operates with no detectable emissions following any time 

the component or connection is repaired or replaced or the 

connection is unsealed. Inspection results shall be submitted in 

the Periodic Report as specified in §63.1285(e)(2)(iii). 
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 (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 §63.1282(b) 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 §63.1285(d)(1) or (2). 

 (B) Conduct annual inspections according to the procedures 

specified in §63.1282(b) to demonstrate that the components or 

connections operate with no detectable emissions. Inspection 

results shall be submitted in the Periodic Report as specified 

in §63.1285(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. 

Inspection results shall be submitted in the Periodic Report as 

specified in §63.1285(e)(2)(iii). 

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

§63.1281(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 
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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 for which leaks 

or defects have been detected is allowed if the repair is 

technically infeasible without a shutdown, as defined in 

§63.1271, 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 
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of such equipment shall be completed 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) and (ii) 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 paragraph (c)(2) (i) or (ii) 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) and (ii) of 

this section if: 

 (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 
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 (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 

§63.1284(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 (97) of this section.

that will allow a determination to be made whether the control 

device is achieving the applicable performance requirements of 

§63.1281(d) or (e)(3). Owners or operators that install and 

operate a flare in accordance with §63.1281(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 §63.1281(d), (e)(3), or (f)(1). The 

Each continuous parameter monitoring system must 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 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;

 (B) Sampling interface (e.g., thermocouple) location such 

that the monitoring system will provide representative 

measurements; 
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 (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.manufacturer's specifications or other written 

procedures that provide reasonable assurance that the monitoring 

equipment is operating properly.

 (2) An owner or operator is exempted from the monitoring 

requirements specified in paragraphs (d)(3) through (97) 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 are used as the primary 

fuel; 
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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 §63.1282(d) 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 ±2 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 representative in the 

combustion chamber downstream 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 temperatures at two 
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locations and have a minimum accuracy of ±2 percent of the 

temperatures being monitored in °C, or ±2.5 °C, whichever value 

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 ±2 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 representative in the combustion chamber downstream 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 percent of the 

temperature being monitored in °C, or ±2.5 °C, whichever value 
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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: 

 (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 

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 ±2 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 §63.1282(d)(3) or a design analysis 

in accordance with §63.1282(d)(4)(i)(F) and shall be based on 

the total carbon working capacity of the control device and 

source operating schedule.
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 (H) For a control device whose model is tested under 

§63.1282(g):

 (1) The owner or operator shall determine actual average 

inlet waste gas flowrate using the model GRI-GLYCalcTM , Version 

3.0 or higher, ProMax, or AspenTech HYSYS. Inputs to the models

shall be representative of actual operating conditions of the 

controlled unit. The determination shall be performed to 

coincide with the visible emissions test under §63.1282(h)(3); 

 (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 flowrate, 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 monitored 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 for condensers. 

 (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 

§63.1281(d)(1), or (e)(3)(ii), or (f)(1). Each minimum or 
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maximum operating parameter value shall be established as 

follows: 

 (A) If the owner or operator conducts performance tests in 

accordance with the requirements of §63.1282(d)(3) to 

demonstrate that the control device achieves the applicable 

performance requirements specified in §63.1281(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 values measured during the performance test 

and supplemented, as necessary, by a control device condenser 

design analysis or control device manufacturer's recommendations 

or a combination of both. 

 (B) If the owner or operator uses a control device 

condenser design analysis in accordance with the requirements of 

§63.1282(d)(4) to demonstrate that the control device achieves 

the applicable performance requirements specified in 

§63.1281(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 device condenser 

design analysis and may be supplemented by the control device 

condenser manufacturer's recommendations.

 (C) If the owner or operator operates a control device 

where the performance test requirement was met under §63.1282(g) 
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to demonstrate that the control device achieves the applicable 

performance requirements specified in §63.1281(d)(1), (e)(3)(ii) 

or (f)(1), then the maximum inlet gas flowrate shall be 

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 §63.1282(d)(3) to 

demonstrate that the condenser achieves the applicable 

performance requirements in §63.1281(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 

§63.1282(d)(4)(i)(D) to demonstrate that the condenser achieves 

the applicable performance requirements specified in 

§63.1281(d)(1), or (e)(3)(ii), or (f)(1), then the condenser 

performance curve shall be based on the condenser design 
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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 

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)(iv) 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)(iv) 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 
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parameter in accordance with the requirements of paragraph 

(d)(5)(i) of this section. 

 (ii) For sources meeting §63.1281(d)(1)(ii), aAn excursion 

occurs when average condenser efficiency calculated according to 

the requirements specified in §63.1282(f)(2)(iii) is less than 

95.0 percent, as specified in §63.1282(f)(3). For sources 

meeting §63.1281(f)(1), an excursion occurs when the 30-day 

average condenser efficiency calculated according to the 

requirements of §63.1282(f)(2)(iii) is less than the identified 

30-day required percent reduction.

 (iii) An excursion occurs when the monitoring data are not 

available for at least 75 percent of the operating hours in a 

day. 

 (iv) 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 §63.1281(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. 

 (B) For each bypass line subject to §63.1281(c)(3)(i)(B), 

if the seal or closure mechanism has been broken, the bypass 
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line valve position has changed, the key for the lock-and-key 

type lock has been checked out, or the car-seal has broken.

 (v) For control devices whose model is tested under 

§63.1282(g), an excursion occurs when:

 (A) The inlet gas flowrate exceeds the maximum established 

during the test conducted under §63.1282(g).

 (B) Failure of the quarterly visible emissions test 

conducted under §63.1282(h)(3).

 (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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(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 §63.1285(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.

§ 63.1284 Recordkeeping requirements. 

 (a) The recordkeeping provisions of subpart A of this part, 

that apply and those that do not apply to owners and operators 

of facilities subject to this subpart are listed in Table 2 of 

this subpart. 

 (b) Except as specified in paragraphs (c) and (d) of this 

section, each owner or operator of a facility subject to this 
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subpart shall maintain the records specified in paragraphs 

(b)(1) through (b)(10) 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 §63.1283(d). Notwithstanding the previous 
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sentence, monitoring data recorded during periods identified in 

paragraphs (b)(3)(i) through (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] Startup, shutdown, and malfunction events. 

During startup, shutdown and malfunction events, the owner or 

operator shall maintain records indicating whether or not the 

startup, shutdown, or malfunction plan, required under 

§63.1272(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 

§63.1283(d)(6)(iii). 

 (4) Each owner or operator using a control device to comply 

with §63.1274 shall keep the following records up-to-date and 

readily accessible: 

 (i) Continuous records of the equipment operating 

parameters specified to be monitored under §63.1283(d) or 
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specified by the Administrator in accordance with 

§63.1283(d)(3)(iii). For flares, the hourly records and records 

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 

§63.1283(d)(4) of this subpart, except as specified in 

paragraphs (b)(4)(ii)(A) through (C) of this section.

 (A) For flares, the records required in paragraph (e) of 

this section.

 (B)_For condensers installed to comply with §63.1275, 

records of the annual 30-day rolling average condenser 

efficiency determined under §63.1282(f) shall be kept in 

addition to the daily averages.

 (C) For a control device whose model is tested under 

§63.1282(g), the records required in paragraph (g) of this 

section.

 (iii) Hourly records of whether the flow indicator 

specified under §63.1281(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 
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stream is diverted from the control device or the monitor device

is not operating. 

 (iv) Where a seal or closure mechanism is used to comply 

with §63.1281(c)(3)(i)(B), hourly records of flow are not 

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 closed-vent system 

that are designated as unsafe to inspect in accordance with 

§63.1283(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 closed-vent system 

that are designated as difficult to inspect in accordance with 

§63.1283(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 

§63.1283(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. 
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 (i) The instrument identification numbers, operator name or 

initials, and identification of the equipment. 

 (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 §63.1282(b) 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 §63.1281(d)(5) and records of each carbon replacement.

 (8) For each inspection conducted in accordance with 

§63.1283(c) during which no leaks or defects are detected, a 
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record that the inspection was performed, the date of the 

inspection, and a statement that no leaks or defects were 

detected. 

 (9) Records of glycol dehydration unit baseline operations 

calculated as required under §63.1281(e)(1). 

 (10) Records required in §63.1281(e)(3)(i) documenting that 

the facility continues to operate under the conditions specified 

in §63.1281(e)(2). 

 (c) An owner or operator that elects to comply with the 

benzene emission limit specified in §63.1275(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) An owner or operator that is exempt from control 

requirements under §63.1274(d) shall maintain the records 

specified in paragraph (d)(1) or (d)(2) of this section, as 
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appropriate, for each glycol dehydration unit that is not 

controlled according to the requirements of §63.1274(c). 

 (1) 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 §63.1282(a)(1); or 

 (2) The actual average benzene emissions (in terms of 

benzene emissions per year), as determined in accordance with 

§63.1282(a)(2). 

 (e) Record the following when using a flare to comply with 

§63.1281(d): 

 (1) Flare design (i.e., steam-assisted, air-assisted, or 

non-assisted);

 (2) All visible emission readings, heat content 

determinations, flowrate measurements, and exit velocity 

determinations made during the compliance determination required 

by §63.1282(d)(2); and 

 (3) All hourly records and other recorded periods when the 

pilot flame is absent.

 (f) 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 
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actions taken during periods of malfunction to minimize 

emissions in accordance with §63.1274(h), including corrective 

actions to restore malfunctioning process and air pollution 

control and monitoring equipment to its normal or usual manner 

of operation.

(g) Record the following when using a control device whose 

model is tested under §63.1282(g) to comply with §63.1281(d), 

(e)(3)(ii) and (f)(1):

 (1) All visible emission readings and flowrate calculations

made during the compliance determination required by 

§63.1282(h); and

 (2) All hourly records and other recorded periods when the 

pilot flame is absent.

 (h) The date the semi-annual maintenance inspection 

required under §63.1283(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.

§ 63.1285 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 facilities subject to this subpart are listed in Table 2 of 

this subpart. 
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 (b) Each owner or operator of a facility subject to this 

subpart shall submit the information listed in paragraphs (b)(1) 

through (b)(6) of this section, except as provided in paragraph 

(b)(7) 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 (b)(1)(ii)

of this section, the initial notification shall be submitted by 

1 year after an 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 §63.1270(d)(3) 

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 [INSERT DATE ONE YEAR AFTER DATE OF PUBLICATION IN 

THE FEDERAL REGISTER], whichever is later. An affected source 

identified under §63.1270(d)(3) that plans to be an area source 
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by [INSERT DATE THREE YEARS AFTER DATE OF PUBLICATION 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 requested 

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. 

 (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; 
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 (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 §63.1274(h), including actions taken to correct 

a malfunction.Startup, shutdown, and malfunction reports, as 

specified in §63.10(d)(5), shall be submitted as required. 

Separate startup, shutdown, or malfunction reports as described 

in §63.10(d)(5)(i) 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 

§63.1275, is exempt from all reporting requirements for major 

sources in this subpart for that unit.

 (c) [Reserved] 
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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 §63.1270(d). 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 (1012) 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 have been submitted at any time prior to 

180 days after the applicable compliance dates specified in 

§63.1270(d), a separate Notification of Compliance Status Report 

is not required. If an owner or operator submits the information 

specified in paragraphs (d)(1) through (120) 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 §63.1274, the owner or operator 

shall submit the information in paragraph (d)(1)(iii) of this 
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section and the information in either paragraph (d)(1)(i), or

(ii) of this section:.

 (i) The condenser design analysis documentation specified 

in §63.1282(d)(4) of this subpart if the owner or operator 

elects to prepare a design analysis; or 

 (ii) If the owner or operator elects to 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 §63.1282(d)(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 §63.1282(g), an electronic copy of the 

performance test results shall be submitted via email to Oil and 

Gas PT@EPA.GOV unless the test results for that model of 

combustion control device are posted at the following website: 

www.???.comepa.gov/airquality/oilandgas/ .

 (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 §63.1282(d)(3) of this 

subpart; and 
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 (B) The value of the monitored parameters specified in 

§63.1283(d) of this subpart, or a site-specific parameter 

approved by the permitting agency, averaged over the full period 

of the performance test.

 (iii) The results of the closed-vent system initial 

inspections performed according to the requirements in 

§63.1283(c)(2)(i) and (ii). 

 (2) If a closed-vent system and a flare are used to comply 

with §63.1274, 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 §63.1282(d)(2) of this subpart, and 

 (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 

§63.1283(c)(2)(i) and (ii).
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 (3) 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. 

 (4) For each control device other than a flare used to meet 

the requirements of §63.1274, the owner or operator shall submit 

the information specified in paragraphs (d)(4)(i) through 

(iiiiv) of this section for each operating parameter required to 

be monitored in accordance with the requirements of §63.1283(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 
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continuously achieve the applicable performance requirements of 

§63.1281(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 §63.1283(d)(5) of this subpart. 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 §63.1281(d)(1), or (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 §63.1281(d)(5)(i).

 (5) Results of any continuous monitoring system performance 

evaluations shall be included in the Notification of Compliance 

Status Report.

 (6) 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 
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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. 

 (7) The owner or operator that elects to comply with the 

requirements of §63.1275(b)(1)(ii) shall submit the records 

required under §63.1284(c). 

 (8) The owner or operator shall submit an analysis 

demonstrating whether an affected source is a major source using 

the maximum throughput calculated according to §63.1270(a). 

 (9) The owner or operator shall submit a statement as to 

whether the source has complied with the requirements of this 

subpart. 

 (10) The owner or operator shall submit the analysis 

prepared under §63.1281(e)(2) to demonstrate that the conditions 

by which the facility will be operated to achieve an overallthe 

HAP emission reduction of 95.0 percent, or the BTEX limit in 

§63.1275(b)(1)(iii) through process modifications or a 

combination of process modifications and one or more control 

devices.
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 (11) If the owner or operator installs a combustion 

control device model tested under the procedures in §63.1282(g), 

the data listed under §63.1282(g)(8).

 (12) For each combustion control device model tested under 

§63.1282(g), the information listed in paragraphs (d)(12)(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 the model of control device was tested by the 

manufacturer.

 (v) Manufacturer’s HAP destruction efficiency rating.

 (vi) Control device operating parameters, maximum allowable 

inlet gas flowrate.

 (e) Periodic Reports. An owner or operator shall prepare 

Periodic Reports in accordance with paragraphs (e)(1) and (2) 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 
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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 (ixiii) 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 §63.1283(d)(6)) shall be 

considered excess emissions. 

 (ii) A description of all excursions as defined in 

§63.1283(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 

maximum operating parameter limit), as specified in 

§63.1283(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 30-day average 

condenser control efficiency is less than 95.0 percentthe value, 

as specified in §63.1283(d)(6)(ii), the report must include the 
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30-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 by lack of monitoring data, 

as specified in §63.1283(d)(6)(iii), the report must include the 

date and duration of period when the monitoring data were not 

collected and the reason why the data were not collected.

 (D) For each excursion caused when the maximum inlet gas 

flowrate identified under §63.1282(g) is exceeded, the report 

must include the values of the inlet gas identified and the date 

and duration of the period that the excursion occurred.

 (E) For each excursion caused when visible emissions 

determined under §63.1282(h) exceed the maximum allowable 

duration, the report must include the date and duration of the 

period that the excursion occurred, repairs affected to the 

unit, and date the unit was returned to service.,

 (iii) For each inspection conducted in accordance with 

§63.1283(c) during which a leak or defect is detected, the 

records specified in §63.1284(b)(7) must be included in the next 

Periodic Report. 

 (iv) For each closed-vent system with a bypass line subject 

to §63.1281(c)(3)(i)(A), records required under 

§63.1284(b)(4)(iii) of all periods when the vent stream is 

diverted from the control device through a bypass line. For each 
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closed-vent system with a bypass line subject to 

§63.1281(c)(3)(i)(B), records required under §63.1284(b)(4)(iv) 

of all periods in which the seal or closure mechanism is broken, 

the bypass valve position has changed, or the key to unlock the 

bypass line valve was checked out. 

 (v) If an owner or operator elects to comply with 

§63.1275(b)(1)(ii), the records required under §63.1284(c)(3). 

 (vi) The information in paragraphs (e)(2)(vi)(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. 

 (vii) Any change in compliance methods as specified in 

§63.1282(e). 

 (viii) If the owner or operator elects to comply with 

§63.1275(c)(2), the records required under §63.1284(b)(10). 

 (ix) For flares, the records specified in §63.1284(e).

 (x) The results of any periodic test as required in 

§63.1282(d)(3) conducted during the reporting period.

 (xi) For each carbon adsorber used to meet the control 

device requirements of §63.1281(d)(1), records of each carbon 

replacement that occurred during the reporting period.
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 (xii) For combustion control device inspections conducted 

in accordance with §63.1283(b) the records specified in 

§63.1284(h).

 (xiii) Certification by a responsible official of truth, 

accuracy, and completeness. This certification shall state that, 

based on information and belief formed after reasonable inquiry, 

the statements and information in the document are true, 

accurate, and complete.

 (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; 

 (3) Revisions to any of the information reported in the 

original Notification of Compliance Status Report under 

paragraph (d) of this section; and
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 (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) Within 60 days after the date 

of completing each performance test (defined in §63.2) as 

required by this subpart you must submit the results of the 

performance tests required by this subpart to EPA’s WebFIRE 

database by using the Compliance and Emissions Data Reporting 

Interface (CEDRI) that is accessed through EPA’s Central Data 

Exchange (CDX)(www.epa.gov/cdx). Performance test data must be 

submitted in the file format generated through use of EPA’s 

Electronic Reporting Tool (ERT) (see 

http://www.epa.gov/ttn/chief/ert/index.html). Only data 

collected using test methods on the ERT website are subject to 

this requirement for submitting reports electronically to 

WebFIRE. Owners or operators who claim that some of the 

information being submitted for performance tests is 

confidential business information (CBI) must submit a complete 

ERT file including information claimed to be CBI on a compact 

disk or other commonly used electronic storage media (including, 

but not limited to, flash drives) to EPA. The electronic media 

must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE 

CBI Office, Attention: WebFIRE Administrator, MD C404-02, 4930 
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Old Page Rd., Durham, NC 27703. The same ERT file with the CBI 

omitted must be submitted to EPA via CDX as described earlier in 

this paragraph. At the discretion of the delegated authority, 

you must also submit these reports, including the confidential 

business information, to the delegated authority in the format 

specified by the delegated authority.

 (2) All reports required by this subpart not subject to the 

requirements in paragraph (g)(1) of this section must be sent to 

the Administrator at the appropriate address listed in §63.13.

The Administrator or the delegated authority may request a 

report in any form suitable for the specific case (e.g., by 

commonly used electronic media such as Excel spreadsheet, on CD 

or hard copy). The Administrator retains the right to require 

submittal of reports subject to paragraph (g)(1) of this section 

in paper format.

§ 63.1286 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. 
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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 

§§63.1270, 63.1274 through 63.1275, 63.1281, and 63.1287. 

 (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. 

 (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. 
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§ 63.1287 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 §§63.1274 through 63.1281, the Administrator 

will publish a notice in the Federal Register 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 showing that this 

means achieves equivalent emission reductions. 

§§ 63.1288-63.1289 [Reserved] 

Appendix to Subpart HH of Part 63—Tables 

Table 1 to Subpart HHH of Part 63—List of Hazardous Air 

Pollutants (HAP) for Subpart HHH 

CAS Numbera Chemical name
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75070 Acetaldehyde

71432 Benzene (includes benzene in gasoline)

75150 Carbon disulfide

463581 Carbonyl sulfide

100414 Ethyl benzene

107211 Ethylene glycol

75050 Acetaldehyde

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 HHH of Part 63—Applicability of 40 CFR Part 

63 General Provisions to Subpart HHH 

General provisions 

reference

Applicable 

to

subpart HHH

Explanation

§63.1(a)(1) Yes.

§63.1(a)(2) Yes.

§63.1(a)(3) Yes.

§63.1(a)(4) Yes.
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§63.1(a)(5) No Section reserved.

§63.1(a)(6) 

through (a)(8)

Yes.

§63.1(a)(9) No Section reserved.

§63.1(a)(10) Yes.

§63.1(a)(11) Yes.

§63.1(a)(12) 

through (a)(14)

Yes.

§63.1(b)(1) No Subpart HHH specifies 

applicability.

§63.1(b)(2) Yes.

§63.1(b)(3) No.

§63.1(c)(1) No Subpart HHH specifies 

applicability.

§63.1(c)(2) No.

§63.1(c)(3) No Section reserved.

§63.1(c)(4) Yes.

§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 HHH.

§63.3(a) through 

(c)

Yes.

§63.4(a)(1) 

through (a)(3)

Yes.

§63.4(a)(4) No Section reserved.

§63.4(a)(5) Yes.
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§63.4(b) Yes.

§63.4(c) Yes.

§63.5(a)(1) Yes.

§63.5(a)(2) No Preconstruction review required 

only for major sources that 

commence construction after 

promulgation of the standard.

§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) Yes.

§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.

§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.
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§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) and 

(c)(4)

No Section reserved.

§63.6(c)(5) Yes.

§63.6(d) No Section reserved.

§63.6(e) Yes.

§63.6(e) Yes Except as otherwise specified.

§63.6(e)(1)(i) No Addressed in §63.1272.See 

§63.1274(h) for general duty 

requirement.

§63.6(e)(1)(ii) YesNo.

§63.6(e)(1)(iii) Yes.

§63.6(e)(2) Yes.

§63.6(e)(3)(i) YesNo. Except as otherwise specified.

§63.6(e)(3)(i)(A) No Addressed by §63.1272(c).

§63.6(e)(3)(i)(B) Yes

§63.6(e)(3)(i)(C) Yes

§63.6(e)(3)(ii) 

through (3)(vi)

Yes

§63.6(e)(3)(vii)

§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 

§63.1272(c).

§63.6(e)(3)(vii) 

(C)

Yes
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§63.6(e)(3)(viii) Yes

§63.6(e)(3)(ix) Yes

§63.6(f)(1) YesNo.

§63.6(f)(2) Yes.

§63.6(f)(3) Yes.

§63.6(g) Yes.

§63.6(h)(1) No.

§63.6(h)(2) 

through (h)(9)

NoYes. Subpart HHH 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.
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§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) No.

§63.8(c)(2) Yes.

§63.8(c)(3) Yes.

§63.8(c)(4) No.

§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.

§63.8(e) Yes Subpart HHH does not specifically 

require continuous emissions 

monitor performance evaluations, 

however, the Administrator can 

request that one be conducted.

§63.8(f)(1) 

through (f)(5)

Yes.

§63.8(f)(6) No Subpart HHH does not require 
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continuous emissions monitoring.

§63.8(g) No Subpart HHH 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.

§63.9(b)(3) Yes.

§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.Yes.

§63.9(g) Yes.

§63.9(h)(1) 

through (h)(3)

Yes.

§63.9(h)(4) No Section reserved.

§63.9(h)(5) and 

(h)(6)

Yes.

§63.9(i) Yes.

§63.9(j) Yes.

§63.10(a) Yes.

§63.10(b)(1) Yes Section 63.1284(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(b)(2) Yes.
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to the CFR for the official version.

§63.10(b)(2)(i) No.

§63.10(b)(2)(ii) No See §63.1284(f) for recordkeeping 

of (1) occurrence and duration and 

(2) actions taken during 

malfunction

§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) No.

§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 

(c)(15)through 

(c)(11)

YesNo See §63.1284(f)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.

§63.10(d)(3) Yes.

§63.10(d)(4) Yes.

§63.10(d)(5) YesNo Subpart HHH requires major sources 

to submit a startup, shutdown and 

malfunction report semiannually.See §63.1285(b)(6) for 
Proposed Subpart HHH Redline/Strikeout April 15, 2012

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This document is not the official version of the proposed rule. Please refer 

to the CFR for the official version.

reporting of malfunctions.

§63.10(e)(1) Yes.

§63.10(e)(2) Yes.

§63.10(e)(3)(i) Yes Subpart HHH requires major sources 

to submit Periodic Reports semiannually.

§63.10(e)(3)(i)(A) Yes.

§63.10(e)(3)(i)(B) Yes.

§63.10(e)(3)(i)(C) No Subpart HHH does not require 

quarterly reporting for excess 

emissions.

§63.10(e)(3)(ii) 

through 

(e)(3)(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.