1. GENERAL PLAN APPROVAL AND/OR GENERAL OPERATING PERMIT
      2. BAQ-GPA/GP-5
      3. Natural Gas Compression Stations, Processing Plants, and Transmission Stations

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COMMONWEALTH OF PENNSYLVANIA
GP-5 PERMIT
DEPARTMENT OF ENVIRONMENTAL PROTECTION
BUREAU OF AIR QUALITY
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GENERAL PLAN APPROVAL AND/OR GENERAL OPERATING PERMIT
BAQ-GPA/GP-5
Natural Gas Compression Stations, Processing Plants, and Transmission Stations
SECTION A. GENERAL REQUIREMENTS
1.
Statutory/Regulatory Authority and General Description
In accordance with Section 6.1(f) of the Pennsylvania Air Pollution Control Act (APCA), 35 P.S. §4006.1(f) and
25 Pa. Code Chapter 127, Subchapter H, the Department of Environmental Protection (Department or DEP) hereby
issues this General Plan Approval and/or General Operating Permit (General Permit or GP-5) for new or modified
natural gas compressor stations, processing plants, and transmission stations (facility or facilities) constructed or
operating in this Commonwealth.
2.
Contents
SECTION A. GENERAL REQUIREMENTS.................................................................................................................... 1
SECTION B. FUGITIVE PARTICULATE MATTER ...................................................................................................... 10
SECTION C. NATURAL GAS-FIRED COMBUSTION UNITS...................................................................................... 10
SECTION D. GLYCOL DEHYDRATION UNITS........................................................................................................... 13
SECTION E. STATIONARY NATURAL GAS-FIRED SPARK IGNITION INTERNAL COMBUSTION ENGINES ....... 15
SECTION F. STATIONARY NATURAL GAS-FIRED COMBUSTION TURBINES....................................................... 19
SECTION G. RECIPROCATING COMPRESSORS..................................................................................................... 23
SECTION H. CENTRIFUGAL COMPRESSORS.......................................................................................................... 24
SECTION I. STORAGE VESSELS ............................................................................................................................... 25
SECTION J. TANKER TRUCK LOAD-OUT OPERATIONS ......................................................................................... 27
SECTION K. FUGITIVE EMISSIONS COMPONENTS ................................................................................................ 28
SECTION L. CONTROLLERS ...................................................................................................................................... 31
SECTION M. PUMPS.................................................................................................................................................... 32
SECTION N. ENCLOSED FLARES AND OTHER EMISSION CONTROL DEVICES ................................................. 33
SECTION O. PIGGING OPERATIONS ........................................................................................................................ 43
3.
Definitions
Words and terms that are not otherwise defined in this General Permit shall have the meanings set forth in Section
3 of the APCA (35 P.S. §4003) and Title 25, Article III including 25 Pa. Code §121.1 unless the context indicates
otherwise. The meanings set forth in applicable definitions codified in the Federal Code of Regulations including
40 CFR Part 60, Subparts KKK, JJJJ, KKKK, OOOO, and OOOOa or 40 CFR Part 63, Subparts HH and ZZZZ shall
also apply to this General Permit.
Coal Bed Methane
– Methane that is extracted from a coal bed and the surrounding rock strata by extraction wells
drilled in advance of a mining operation, which is typically of pipeline quality.
Deviation
– An instance in which an affected source or the owner or operator of an affected source fails to meet any
term or condition of this General Permit, including any emission limit, operating limit, or work practice standard,
including during startup, shutdown, or malfunction regardless of whether such a failure is permitted.
Difficult-To-Monitor
– A fugitive emissions component that cannot be monitored without elevating the monitoring
personnel more than 6.6 feet above the surface may be designated difficult-to-monitor for purposes of Section K.

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Fugitive Emissions Component
– Any component that has the potential to emit fugitive emissions of methane,
VOC, or HAP at a natural gas compressor station, processing plant, or transmission station including, but not limited
to, valves, connectors, pressure relief devices, open-ended lines, flanges, compressors, instruments, meters, covers,
and closed vent systems. Devices that vent as part of normal operations are not considered fugitive sources unless
the emission originates from a place other than the vent.
Gob Gas
– Methane that is mixed with air from a mine ventilation system due to the mining operation reaching the
area of an extraction well, which is typically below pipeline quality.
Haul Road
– A road owned or operated by the permittee which is used to facilitate the movement of people,
equipment, and/or materials to and from a facility.
Leak
– A leak is defined as any release of gaseous hydrocarbons that is detected by Auditory, Visual, or Olfactory
(AVO) inspection; an optical gas imaging (OGI) camera; a gas leak detector that meets the requirements of 40 CFR
Part 60, Appendix A-7, Method 21; or other leak detection methods approved by the Department’s Division of Source
Testing and Monitoring. However, a release from any equipment or component designed by the manufacturer to
protect the equipment, controller, or personnel or to prevent groundwater contamination, gas migration, or an
emergency situation is not considered a leak.
Malfunction
– Any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment,
process equipment, or a process to operate in a normal or usual manner.
Failures caused in part by poor
maintenance or careless operation are not malfunctions. Malfunctions include, but are not limited to, triggering of
emergency shutdown devices and unscheduled blowdowns.
Natural Gas Compressor Station
– A facility that compresses and/or processes natural gas, coal bed methane, or
gob gas prior to the point of custody transfer using processes including, but not limited to, gas dehydration,
compression, pigging, and storage.
Natural Gas Processing Plant
– A facility that engages in the extraction of natural gas liquids from field gas, the
fractionation of mixed natural gas liquids to natural gas products, or both extracts and fractionates natural gas liquids.
Natural Gas Transmission Station
– A facility that compresses and/or processes natural gas after the point of
custody transfer using processes including, but not limited to, gas dehydration, compression, pigging, and storage.
Pigging Operations
– The process of removing and collecting condensed liquids including condensate, intermediate
hydrocarbons, or produced water, from a pipeline using a spherical or bullet shaped device, known as a pig, forced
through the pipeline by natural gas pressure. The liquids are then collected at their eventual destination in a storage
tank, often referred to as a slug tank.
Point of Custody Transfer
– The location after the processing and/or treatment of natural gas in the production
sector, typically after a natural gas processing plant, where control and/or ownership of the natural gas is transferred
from one owner or operator to another.
Sour Gas
– Natural gas where the H
2
S content is in excess of 4 ppmv at standard temperature and pressure.
Unsafe-To-Monitor
– A fugitive emissions component that cannot be monitored because monitoring personnel
would be exposed to immediate danger while conducting a monitoring survey may be designated unsafe-to-monitor
for purposes of Section K.
4.
Applicability/Scope
(a)
This General Permit authorizes the construction, modification, and/or operation of a natural gas compressor
station, processing plant, or transmission station. The applicability of this General Permit may include one or
more of the following operations or emission sources:
(i)
Fugitive Particulate Matter

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(ii)
Natural Gas-Fired Combustion Units
(iii)
Glycol Dehydration Units
(iv)
Stationary Natural Gas-Fired Spark Ignition Internal Combustion Engines
(v)
Stationary Natural Gas-Fired Combustion Turbines
(vi)
Reciprocating Compressors
(vii)
Centrifugal Compressors
(viii) Storage Vessels
(ix)
Tanker Truck Load-Out Operations
(x)
Fugitive Emissions Components
(xi)
Controllers
(xii) Pumps
(xiii) Enclosed Flares and Other Emission Control Devices
(xiv) Pigging Operations
(b)
An Application for Authorization to Use GP-5 may be submitted for the operation of an eligible source if the
source is exempted from plan approval requirements under 25 Pa. Code §127.14.
(c)
If any source located at the facility cannot be regulated under this General Permit, a plan approval and/or an
operating permit issued in accordance with 25 Pa. Code, Chapter 127, Subchapter B and/or Subchapter F will
be required.
5.
Prohibited Use of GP-5
GP-5 may not be used for the construction, modification, or operation of any of the following air contamination
sources:
(a)
A proposed source located at a Title V facility including sources determined to be a single source Title V
facility.
(b)
A proposed source that is subject to Title V permitting requirements specified in 25 Pa. Code Chapter 127,
Subchapters F and G; prevention of significant deterioration requirements specified in 25 Pa. Code Chapter
127 Subchapter D; or nonattainment new source review requirements specified in 25 Pa. Code
Chapter 127 Subchapter E.
(c)
A facility that produces or processes sour gas.
(d)
Circumvention.
(i)
The owner or operator of a facility may not circumvent the new source review requirements of 25 Pa.
Code Chapter 127, Subchapter E by causing or allowing a pattern of ownership or development,
including the phasing, staging, delaying, or engaging in incremental construction over a geographic area
of a facility which, except for the pattern of ownership or development, would otherwise require a permit
or submission of a plan approval application.
(ii)
No person may permit the use of a device, stack height that exceeds good engineering practice,
dispersion technique, or other technique that, without resulting in reduction of the total amount of air
contaminants emitted, conceals or dilutes an emission of air contaminants that would otherwise be in
violation of this General Permit, the APCA, or the regulations promulgated thereunder, except for those
that are used for the control of malodors with the prior written approval of the Department.
6.
Authorization to Use GP-5
(a)
Application for Authorization to Use GP-5.
Pursuant to 25 Pa. Code §127.621, any person proposing to
construct, operate, or modify a source listed in Section A, Condition 4 of this General Permit at a natural gas
compressor station, processing plant, or transmission station shall submit an Application for Authorization to
Use GP-5 to the Air Program Manager of the appropriate DEP Regional Office responsible for authorizing the
use of general permits in the county in which the facility will be located.
(i)
This application shall be accompanied by:
(A)
The Compliance Review Form required under 25 Pa. Code §127.12a and §127.412, which details
the compliance history of the organization seeking Authorization to Use GP-5;
(B)
The General Information Form 1300-PM-BIT0001 found at
http://www.elibrary.dep.state.pa.us/
;
(C)
The appropriate application fees as specified in Condition 7;

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(D)
Proof of the municipal notification as required in Condition 10(a);
and
(E)
Any additional forms or information requested by the Department.
(ii)
This application shall be submitted to DEP either by hand delivery, courier, or sent to DEP by certified
mail, return receipt requested in accordance with 25 Pa. Code §127.621(b).
(iii)
An electronic copy of this application may be submitted to the appropriate email address in Condition
10(b)(iv).
(b)
Terms of Authorization to Use GP-5.
This General Permit authorizes the construction and/or operation of the
specific sources and the specific facility as described in the application for a term of five years from the date of
authorization. The authorization to construct a source or facility will expire 18 months from the date of the
authorization if the owner or operator fails to commence construction or if there is a lapse in construction of 18
months. The Department may extend the 18 month period upon an owner or operator providing satisfactory
justification for an extension up to the original date of the five year term. All requests for extension shall be
submitted to the Department at least 30 days prior to the end of the 18 month period and are only valid upon
receipt of written approval by the Department. The expiration of the authorization to construct will require a
new Application for Authorization to Use GP-5 if an extension is not requested and granted.
(c)
Expiration of and Re-Authorization to Use GP-5.
(i)
The authorization granted by the Department to construct and/or operate under this General Permit shall
terminate on the date of expiration unless a complete Application for Authorization to Use GP-5 is
submitted to the Department at least 30 calendar days prior to the expiration date.
(ii)
Upon receipt by the Department of a timely, administratively and technically complete application for
re-authorization to operate under this General Permit, the owner or operator may continue to operate the
facility subject to final action by the Department provided that the sources and the facility are operated in
compliance with the terms and conditions of this General Permit. The Authorization to Use GP-5 shall
cease if the owner or operator fails to submit any additional information requested by the Department to
process the application by the specified deadline.
(d)
Transfer of Ownership.
The Authorization to Use GP-5 may not be transferred from the owner or operator of a
facility except when the change of ownership is demonstrated to the satisfaction of the Department and the
Department approves the transfer in writing. Within 30 calendar days after a change of ownership of the
facility, the new owner or operator shall submit to the Air Program Manager of the appropriate Regional Office
an Application for Authorization to Use GP-5 in accordance with Condition (a) above.
(e)
Administrative Amendment.
In the event of a change in the name, address, or phone number of a person
identified in the General Permit or a similar minor administrative change at the facility, in accordance with
25 Pa. Code §127.450, the Department may authorize an administrative amendment. The owner or operator
shall submit a brief description of the change and the date on which the change is to occur in a letter signed by
the Responsible Official with the fee specified in Condition 7(d) to the Air Program Manager of the appropriate
Regional Office.
(f)
Modification, Suspension, or Revocation of GP-5 or Authorizations to Use GP-5.
(i)
The Department may modify, suspend, or revoke and reissue this General Permit if it is determined that
GP-5 does not comply with the Clean Air Act, the APCA, or regulations adopted under the acts.
(ii)
This General Permit may be modified, suspended, or revoked if the Department determines that the
natural gas compressor station, processing plant, or transmission station cannot be adequately regulated
under this General Permit.
(iii)
An Authorization to Use GP-5 may be suspended or revoked if the Department determines that, at any
time, the owner or operator has failed to construct and/or operate the facility in compliance with the terms
and conditions of this General Permit, the specifications in the Application for Authorization to Use GP-5,
or the information provided in the supplemental material included with the application used to determine
if the proposed sources will comply with the GP-5.
(iv)
Upon suspension or revocation of an Authorization to Use GP-5, the owner or operator shall immediately
cease construction and/or operation of the facility. The owner or operator of the facility shall not restart
construction and/or operation prior to the receipt of written approval from the Department.

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7.
General Permit Fees
Each applicant seeking Authorization to Use GP-5 shall submit the applicable fees required under this Condition to
the appropriate DEP Regional Office. The following fee schedules apply to this General Permit:
(a)
General Plan Approval Application Fee, payable upon submission of the application:
$1,700
(b)
General Operating Permit Application Fee, payable upon submission of the application:
$ 375
(c)
Annual Operating Permit Administration Fee, payable by March 1
st
for the previous calendar year: $ 375
(d)
Administrative Amendment Fee, payable upon submission of the letter in Condition 6(e):
$ 300
(e)
The Department may increase the applicable fees for this General Plan Approval/General Operating Permit in
accordance with the applicable fee schedules in 25 Pa. Code Chapter 127, Subchapter I following notice in the
Pennsylvania Bulletin
.
8.
Applicable Laws
(a)
Where ever possible, the terms and conditions of this General Permit have been streamlined to satisfy both
federal and state requirements. It is the duty of the Responsible Official, as defined in 25 Pa. Code §121.1, to
ensure that the facility is in compliance with all applicable federal, state, and local laws and regulations,
including 25 Pa. Code, Subpart C, Article III. Nothing in this General Permit relieves the Responsible Official
from this obligation to comply.
(b)
Applicable federal regulations include, but are not limited to, the following New Source Performance Standards
(NSPS), codified at 40 CFR Part 60 and incorporated by reference in 25 Pa. Code §122.3, and National
Emission Standards for Hazardous Air Pollutants (NESHAP), codified at 40 CFR Part 63 and incorporated by
reference in 25 Pa. Code §127.35:
(i)
40 CFR Part 60, Subpart KKK
– Standards of Performance for Equipment Leaks of VOC from Onshore
Natural Gas Processing Plants for which Construction, Reconstruction, or Modification Commenced After
January 20, 1984, and On or Before August 23, 2011.
(ii)
40 CFR Part 60, Subpart JJJJ
– Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines.
(iii)
40 CFR Part 60, Subpart KKKK
– Standards of Performance for Stationary Combustion Turbines.
(iv)
40 CFR Part 60, Subpart OOOO
– Standards of Performance for Crude Oil and Natural Gas Production,
Transmission, and Distribution for which Construction, Modification, or Reconstruction Commenced after
August 23, 2011, and on or before September 18, 2015.
(v)
40 CFR Part 60, Subpart OOOOa
– Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification, or Reconstruction Commenced after September 18, 2015.
(vi)
40 CFR Part 63, Subpart HH
– National Emission Standards for Hazardous Air Pollutants from Oil and
Natural Gas Production Facilities.
(vii)
40 CFR Part 63, Subpart ZZZZ
– National Emission Standards for Hazardous Air Pollutants for
Reciprocating Internal Combustion Engines.
9.
Compliance Requirements and Compliance Certification
(a)
The emissions from all sources and associated air pollution control equipment located at a natural gas
compressor station, processing plant, or transmission station and other sources determined by the Department
to be a single source shall not equal or exceed either of the following on a 12-month rolling sum basis:
(i)
Nitrogen Oxides (NO
X
) – 100 tons
(ii)
Carbon Monoxide (CO) – 100 tons
(iii)
Sulfur Oxides (SO
X
) – 100 tons
(iv)
Particulate Matter with an aerodynamic diameter less than 10 microns (PM
10
) – 100 tons
(v)
Particulate Matter with an aerodynamic diameter less than 2.5 microns (PM
2.5
) – 100 tons
(vi)
Volatile Organic Compounds (VOCs) – 50 tons
(vii)
Any individual Hazardous Air Pollutant (HAP) – 10 tons
(viii) Total Hazardous Air Pollutants (HAPs) – 25 tons.

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(ix)
In addition, the emissions from all sources and associated air pollution control equipment located at a
facility in Bucks, Chester, Delaware, Montgomery, or Philadelphia counties shall not equal or exceed any
of the following on a 12-month rolling sum basis:
(A)
NO
X
– 25 tons
(B)
VOCs – 25 tons.
(b)
The facility throughput and/or equipment hours of operation shall be constrained as necessary to not exceed
any facility-wide emissions cap required in (a) above.
(c)
All sources and associated air pollution control equipment located at a facility shall be:
(i)
Operated in such a manner as not to cause air pollution, as that term is defined in 25 Pa. Code §121.1;
(ii)
Operated and maintained in accordance with the manufacturer’s specifications, procedures,
recommended maintenance schedule, and the specifications in the Application for Authorization to Use
GP-5, or an alternate procedure approved by the Department that achieves equal or greater emissions
reductions in accordance with 25 Pa. Code §127.12b;
and
(iii)
Operated and maintained in such a manner that malodors are not detectable outside the property of the
owner or operator on whose land the facility is being operated in accordance with 25 Pa. Code §123.31.
(d)
The owner or operator of an existing facility where new equipment is installed becomes a modified facility with
respect to the fugitive emissions components requirements of Section K as per 40 CFR §60.5365a(i).
(e)
This General Permit cannot be used to relax best available technology or other emission limitations or
requirements previously established through the air quality permitting process.
(f)
An owner or operator of a facility may apply to the Department for a plan approval for any air contamination
source in lieu of seeking authorization to use the General Permit for natural gas compressor stations,
processing plants, or transmission stations.
(g)
The owner or operator authorized to use this General Permit shall comply with the specifications in the
application and the terms and conditions of this General Permit.
(h)
The owner or operator of the facility shall submit to the Air Program Manager of the appropriate DEP Regional
Office an annual certification of compliance with the terms and conditions in the GP-5 for the previous year,
including the emission limitations, standards, or work practices. This Compliance Certification Form must be
included in the annual report as outlined in Condition 12(c).
10.
Notification Requirements
(a)
Municipal Notification.
The facility owner or operator proposing to use this General Permit shall notify the local
municipality and county where the air pollution source is to be located that they have applied for an
Authorization to Use GP-5. The notification shall clearly describe the proposed sources and/or modifications.
(b)
The owner or operator shall notify the Department, by email, no later than five business days after the following
activities:
(i)
Initial commencement date of construction of a source authorized under this General Permit.
(ii)
Final completion date of construction of a source authorized under this General Permit.
(iii)
Any lapse of construction activity of 18 months or more that may occur between the initial and final
construction dates in (i) and (ii) above.
(iv)
The email addresses for the notifications are as follows:
(A)
For the Northeast Regional Office:
ER, GP-5 Submittals NERO
(B)
For the Southeast Regional Office:
ER, GP-5 Submittals SERO
(C)
For the North Central Regional Office:
ER, GP-5 Submittals NCRO
(D)
For the South Central Regional Office:
ER, GP-5 Submittals SCRO
(E)
For the Northwest Regional Office:
ER, GP-5 Submittals NWRO
(F)
For the Southwest Regional Office:
ER, GP-5 Submittals SWRO
(G)
For the Philadelphia Air Management Services:
ER, GP-5 Submittals AMS
(H)
For the Allegheny County Health Department:
ER, GP-5 Submittals ACHD
(c)
The owner or operator shall notify the Air Program Manager of the appropriate DEP Regional Office, in writing,
at least five business days prior to the commencement of operation of a source of their intent to do so. When

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multiple sources at the facility are subject to different commencement of operation schedules, written notice
shall be submitted to DEP prior to the commencement of operation of each source.
(d)
Malfunctions.
(i)
Any malfunction that poses an imminent danger to the public health, safety, or welfare or to the
environment including, but not limited to, fire, explosion, or exceedance of 50% of the lower explosive
limit, shall be reported by telephone to the County Emergency Management Agency and by telephone or
email to the Air Program Manager of the appropriate DEP Regional Office no later than one hour after
the discovery of an incident. Following the telephone or email notification, a written notice as specified in
(iv) below shall be submitted to the DEP within three business days.
(ii)
The owner or operator shall notify the Air Program Manager of the appropriate DEP Regional Office by
telephone or email within 24 hours of the discovery of any malfunction that does not pose an imminent
danger to the public health, safety, or welfare or to the environment as described in the
GP-5 Malfunction
Reporting Instructions
posted on the Department’s website. This also includes any emergency shutdown
or unscheduled blowdown or venting. Following the telephone or email notification, a written notice as
specified in (iv) below shall be submitted to DEP within five business days.
(iii)
If the owner or operator is unable to provide notification by telephone to the Air Program Manager of the
appropriate DEP Regional Office within 24 hours of the discovery of a malfunction due to a weekend or
holiday, the notification shall be made to the Department no later than 4 pm on the first business day
following the weekend or holiday.
(iv)
Written notification shall include:
(A)
The name, GP-5 authorization number, and location of the facility;
(B)
The nature and cause of the malfunction or incident;
(C)
The date and time when the malfunction, incident, or breakdown was first discovered;
(D)
The expected duration of increased emissions;
(E)
The estimated rate of emissions for all criteria, hazardous, and greenhouse gas pollutants;
and
(F)
Any changes to the equipment or modification of the procedures that will prevent reoccurrences of
the malfunction.
(v)
The owner or operator shall notify the Air Program Manager of the appropriate DEP Regional Office by
telephone or email within 24 hours of when corrective measures have been implemented. Following the
telephone or email notification, a written notice shall be submitted to the Department within five business
days.
(vi)
Any emissions due to a malfunction are to be reported in the annual emissions inventory report required
in Condition 12(d).
(e)
The owner or operator shall notify the Air Program Manager of the appropriate DEP Regional Office, by
telephone or email, at least 24 hours prior to any scheduled blowdown or venting. Any emissions due to the
scheduled event are to be reported in the annual emissions inventory report required in accordance with
Condition 12(d).
11.
Recordkeeping Requirements
(a)
All records required must be maintained onsite or at the nearest local field office for a minimum of 5 years and
may be maintained in electronic format.
(b)
The owner or operator of the facility shall generate and maintain records that clearly demonstrate to the
Department that the facility is not a Title V facility and that the facility is in compliance with facility-wide
emission limitations. At a minimum, the records shall be maintained on a monthly basis, and the emissions
shall be calculated on a 12-month rolling sum. The Department reserves the right to request additional
information necessary to determine compliance with the General Permit.
(c)
Public Records and Confidential Information.
(i)
As required under Section 13.2 of the APCA, 35 P.S. §4013.2, the records, reports, or information
obtained by the Department under this General Permit shall be available to the public, except as
provided in paragraph (ii) below.

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(ii)
Upon cause shown by the owner or operator that the records, reports, or information, or a particular
portion thereof to which the Department has access under the APCA that if made public would divulge
production or sales figures or methods, processes, or production unique to that person or would
adversely affect the competitive position of that person by revealing trade secrets, including intellectual
property rights, the Department will consider the record, report, or information, or particular portion
thereof, confidential in the administration of the APCA. Emission data is not eligible for confidentiality.
12.
Reporting Requirements
(a)
The owner or operator of a natural gas compressor station, processing plant, or transmission station shall
submit to the Air Program Manager of the appropriate DEP Regional Office all requests, reports, applications,
submittals, and other communications concerning applicable federal NSPS and NESHAP.
(b)
In accordance with 40 CFR §60.4 and 40 CFR §63.10, copies of all requests, reports, applications, submittals,
and other communications shall also be submitted to the EPA via the Compliance and Emissions Data
Reporting Interface (CEDRI) accessible at
https://cdx.epa.gov
unless electronic reporting is not available, in
which case a copy shall be sent to the following address:
United States Environmental Protection Agency, Region III
Office of Air Enforcement and Compliance Assistance (3AP20)
1650 Arch St.
Philadelphia, PA 19103-2029
(c)
The annual report is required to be submitted either by hand-delivery, courier, or sent by certified mail, return
receipt requested, to the Air Program Manager of the appropriate DEP Regional Office and in electronic format
to the appropriate email address in Condition 10(b)(iv), no later than March 1
st
each year for the previous
calendar year. The initial compliance period may be less than one full year. General information required on
all reports includes:
(i)
Company Name;
(ii)
Facility Site Name;
(iii)
The GP-5 authorization number;
(iv)
Either:
(A)
The address of the site;
or
(B)
A description of the site and the location using latitude and longitude coordinates of the site in
decimal degrees to an accuracy and precision of 5 decimal degrees using the North American
Datum of 1983;
(v)
The beginning and ending dates of the reporting period;
(vi)
The Certification Form described in Condition 9(h), which must include:
(A)
The statement: “Based on information and belief formed after reasonable inquiry, the
statements and information in the document are true, accurate, and complete.”;
and
(B)
The signature of the certifying Responsible Official;
(vii)
Identification of each source included in the report;
(viii) The identification of each term or condition of the GP-5 that is the basis of the certification,
the compliance status, and the methods used for determining the compliance status of the
source, currently and over the reporting period as identified in Sections B. through O. of
this General Permit;
and
(ix)
The records of the facility’s emissions that show it is not a Title V facility as per Condition
11(b).
(d)
In accordance with 25 Pa. Code §135.3, the owner or operator of a facility shall submit to the Department via
AES*Online or AES*XML at
www.depgreenport.state.pa.us/
by March 1
st
of each year, a facility inventory
report for the preceding calendar year for all sources regulated under this General Permit. The inventory report
shall include all emissions information for all sources operated during the preceding calendar year from the
annual report required in (c) above. Emissions data including, but not limited, to the following shall be
reported:

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(i)
NO
X
;
(ii)
CO;
(iii)
SO
X
;
(iv)
PM
10
;
(v)
PM
2.5
;
(vi)
VOCs;
(vii)
Speciated HAP including, but not limited to, benzene, ethyl benzene, formaldehyde, n-hexane, toluene,
isomers and mixtures of xylenes, and 2,2,4-trimethylpentane;
(viii) Total HAPs;
(ix)
CO
2
;
(x)
CH
4
;
and
(xi)
N
2
O.
13.
Source Testing Requirements
(a)
In addition to the specific performance testing requirements included in this General Permit, the Department
may require the owner or operator to conduct a source test if it is determined that the air contaminant
emissions from a source operating under this General Permit are, or may be, in excess of an applicable air
contaminant emission limitation.
(b)
All testing, with the exception of periodic monitoring, shall be performed in accordance with any applicable
federal regulations, 25 Pa. Code, Chapter 139, and the current version of the Department’s Source Testing
Manual, or an alternative test method as approved by the Department.
(c)
All submittals, with the exception of periodic monitoring data, shall meet the applicable requirements specified
in the most current version of the Department’s Source Testing Manual.
(d)
Two copies of all reports, protocols, and test completion notifications, with the exception of periodic monitoring
data, shall be submitted either by hand-delivery, courier, or sent by certified mail, return receipt requested, to
the Air Program Manager of the appropriate DEP Regional Office. An electronic copy shall also be submitted
via the appropriate email address in Condition 10(b)(iv).
(e)
At least 60 calendar days prior to commencing an emission testing program to demonstrate compliance
required by this General Permit, a Test Protocol shall be submitted to in accordance with (d) above for review
and approval. The emissions testing shall not commence prior to receipt of a protocol acceptance letter from
the Department.
(f)
At least 15 calendar days prior to commencing an emission testing program to demonstrate compliance
required by this General Permit, written notification of the date and time of testing shall be provided to the
Department’s Division of Source Testing and Monitoring and the appropriate DEP Regional Office so that an
observer may be present.
The Department is under no obligation to accept the results of any testing
performed without adequate advance written notice to the Department of such testing.
(g)
Within 15 calendar days after completion of the on-site testing portion of an emission test program to
demonstrate compliance required by this General Permit, if a complete test report has not yet been submitted,
an electronic notification shall be submitted in accordance with (d) above indicating the completion date of the
on-site testing.
(h)
A complete test report shall be submitted in accordance with (d) above no later than 60 calendar days after
completion of the on-site testing portion of an emission test program required by this General Permit. The
complete test report shall include a summary at the beginning of the report which includes:
(i)
A statement that the owner or operator has reviewed the report from the emissions testing company and
agrees with the findings;
(ii)
The GP-5 authorization number and conditions that are the basis for the evaluation;
(iii)
A summary of results with respect to each applicable permit condition;
and
(iv)
A statement of compliance or non-compliance with each applicable permit condition.

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SECTION B. FUGITIVE PARTICULATE MATTER
1.
Compliance Requirements
The owner or operator of a facility shall take all reasonable actions to prevent particulate matter from becoming
airborne. Therefore, in accordance with 25 Pa. Code §§123.1 and 123.2, the owner or operator must implement
fugitive dust control measures which at a minimum include:
(a)
Preventing emissions that are visible at the point they move outside the property boundaries and the tracking
of dirt or soils onto public roads by implementing measures including, but not limited to, sweeping and/or the
use of a tire washing system.
(b)
Promptly removing earth or other material that is deposited by trucking or other means on public roadways.
(c)
Applying water or other chemical dust suppressants as needed to haul roads, the shoulders of access
roadways, and the shoulders of public highways for a distance of 500 feet in both directions to reduce fugitive
dusts based on daily site conditions.
(i)
The application of dust suppressants on public highways shall be done in accordance with the
appropriate PennDOT Bulletins.
(ii)
If water is used, it shall not be applied if the result would be a potentially unsafe condition.
(iii)
Waste oil or wastewater shall not be used as a dust suppressant.
(d)
Posting signage consistent with PennDOT regulations on haul roads before the commencement of facility
construction imposing a 15 mph speed limit.
(e)
Posting signage that complies with 67 Pa. Code §212.101(a) and (b) informing drivers of diesel-powered motor
vehicles of the Pennsylvania anti-idling law, limiting idling to no more than 5 minutes in any continuous
60-minute period except for the exemptions and exclusions of 35 P.S. §4603(b) and (c).
(f)
To demonstrate compliance, the owner or operator must submit the required notifications and reports and
maintain the required records.
2. Notification Requirements
The notifications of Section A Condition 10(b) through (d) do not apply to fugitive particulate matter emissions.
3. Recordkeeping Requirements
The owner or operator must keep a written procedures document that describes the activities utilized at the facility to
control fugitive particulate matter on-site and sufficient records to demonstrate that the activities are being
implemented. All records must be kept in accordance with Section A Condition 11.
4. Reporting Requirements
In the required annual report of Section A Condition 12(c), the records of activities implemented in accordance with
the procedures document during the reporting period covered must be included.
Emissions of fugitive particulate matter are not required to be reported under Section A Condition 12(d).
SECTION C. NATURAL GAS-FIRED COMBUSTION UNITS
1.
Compliance Requirements
(a)
Combustion units including, but not limited to, heated flash separator units, evaporator units, fractionation
column heaters, and glycol dehydrator reboilers constructed on or after (effective date of GP-5) shall have a
rated heat input less than 50 MMBtu/h each and only be fired on natural gas.
(i)
For combustion units with a rated heat input of greater than or equal to 10 MMBtu/h, the owner or
operator shall:

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(A)
Ensure that the emission limits in the following table are met:
Constructed
After:
NO
X
(ppmdv
@ 3%
O
2
)
CO
(ppmdv
@ 3%
O
2
)
PM
(lb/MMBtu)
Opacity
(No more than 3
minutes in an
hour)
Opacity
(At any
time)
December 2, 1995
30
300
0.4
20%
60%
(effective date of
GP-5)
15
130
0.4
10%
30%
(B)
Install, operate, and maintain a fuel flow meter;
(C)
Either conduct a performance test in accordance with Condition 5 below within 180 days of initial
startup and within 180 days of reauthorization of the GP;
or
conduct a periodic monitoring in
accordance with Condition 6 below in lieu of the performance test requirement of (C) above;
(D)
Ensure the combustion unit meets the visible emissions standards, as determined by the methods
described in 25 Pa. Code §123.43 once per month;
(E)
Conduct, on an annual basis, a tune-up/inspection which at a minimum shall include:
(1)
Inspecting the burner and cleaning or replacing any components of the burner as necessary;
(2)
Inspecting the flame pattern and adjusting the burner as necessary to optimize the flame
pattern consistent with the manufacturer’s specifications or good combustion engineering
practices;
(3)
Inspecting the system air-to-fuel ratio controller and ensuring it is calibrated and functioning
properly;
(4)
Optimizing total emissions of CO consistent with the NO
X
requirement and the
manufacturer’s specifications or good combustion engineering practices;
and
(5)
Measuring the concentrations in the effluent stream of CO, in ppmv and O
2
in volume
percent before and after adjustments are made in accordance with Condition 6 below.
(F)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(ii)
For combustion units with a rated heat input less than 10 MMBtu/h, the owner or operator shall
demonstrate compliance by submitting the notifications of Condition 2, the reports of Condition 4(a), (b),
and (e), and maintaining the records of Condition 3(a) through (c), (h), and (i).
(b)
Integrated equipment, such as controllers (Section L), pumps (Section M), and any fugitive emissions
components (Section K) are subject to the requirements of their respective Sections.
2.
Notification Requirements
Notifications for each combustion unit must be done in accordance with Section A Condition 10(b) through (d).
Notifications for performance testing of each combustion unit must be done in accordance with Section A Condition
13(f) and (g).
3.
Recordkeeping Requirements
For each combustion unit, the owner or operator shall maintain the following records in accordance with Section A
Condition 11, including information on:
(a)
The location of the combustion unit;
(b)
The monthly fuel usage of the combustion unit;
(c)
The monthly throughput of the combustion unit;
(d)
The visible emissions inspection records;
(e)
Either the summary for each complete test report described in Section A Condition 13(h);
or
the results of each
periodic monitoring;
(f)
The annual tune-up/inspection records, which shall at a minimum include:
(i)
The date the tune-up/inspection was conducted;
(ii)
The concentrations in the effluent stream of CO in ppmv and O
2
in volume percent as determined in
Condition 1(a)(i)(E)
(5)
;

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(iii)
A description of any corrective actions taken as part of the tune-up.
(g)
The emissions calculations for the combustion unit;
and
(h)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each combustion unit operated
during the reporting period shall include:
(a)
The records of the monthly fuel usage of each combustion unit;
(b)
The records of the monthly throughput of each combustion unit;
(c)
The records of the monthly visible emissions inspections;
(d)
Either the summary for each complete test report described in Section A Condition 13(h);
or
the records of the
results of each periodic monitoring;
(e)
The records of the annual tune-up inspection;
and
(f)
The records of any deviations and malfunctions.
The emissions from each combustion unit operated during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).
5.
Performance Testing Requirements
(a)
When conducting a performance test for a combustion unit, the owner or operator may follow the procedure
detailed in (b) below and forego the need to submit the test protocol described in Section A. Condition 13(e). If
the owner or operator decides to use other methods, such as those outlined in 40 CFR Part 60 Subpart A, they
must submit the test protocol described in Section A. Condition 13(e) for review and approval.
(b)
Standardized Performance Test Procedure.
(i)
Conduct three test runs of at least one hour duration within 10% of the highest achievable load.
(ii)
Select the sampling port location and the number and location of traverse points at the exhaust using
40 CFR Part 60, Appendix A-1, Method 1 or 1A depending on stack diameter.
(iii)
Determine the effluent characteristics including:
(A)
The flow velocity, stack temperature, static pressure, and barometric pressure using 40 CFR Part
60, Appendix A-1, Method 2 or 2C depending on stack diameter;
(B)
The gas density using 40 CFR Part 60, Appendix A-2, Method 3A;
and
(C)
The moisture content using 40 CFR Part 60, Appendix A-3, Method 4.
(iv)
Simultaneous to the determination of the O
2
concentration in (iii)(B) above, determine:
(A)
The NO
X
concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 7E;
(B)
The CO concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 10;
and
(C)
The total PM using 40 CFR Part 60, Appendix A-3, Method 5 for filterable PM and 40 CFR Part 51,
Appendix M, Method 202 for condensable PM.
(c)
If at any time the owner or operator operates the combustion unit in excess of the highest achievable load plus
10%, the owner or operator must perform a stack test within 180 days from the anomalous operation.
6.
Periodic Monitoring Requirements
(a)
When conducting periodic monitoring on a combustion unit, the owner or operator may follow the procedures in
(b) below. If the owner or operator decides to deviate from those procedures, they must submit a request to
use an alternate procedure, in writing, at least 60 days prior to performing the periodic monitoring. In the
alternate procedure request, the owner or operator must demonstrate the alternate procedure’s equivalence to
the standard procedure to the satisfaction of the Division of Source Testing and Monitoring.
(b)
Standardized Periodic Monitoring Procedure.
(i)
Conduct three test runs of at least 20 minutes duration within 10% of the highest achievable load.
(ii)
Determine NO
X
and CO emissions concentrations in the exhaust with an electro-chemical cell portable
gas analyzer used and maintained in accordance with the manufacturer’s specifications and following the
procedures specified in ASTM D6522.

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(iii)
If the measured NO
X
or CO emissions concentrations are within the margin of instrument error
or
in
exceedance of the emissions limit, the owner or operator must perform a stack test within 180 days of
the periodic monitoring.
(c)
If the combustion unit passes the monitoring procedure of (b) above and the monthly visible emissions
inspections required by Condition 1(a)(i)(D) of this section are within the limits of Condition 1(a)(i)(A) of this
section, the requirement for a PM performance test is waived.
SECTION D. GLYCOL DEHYDRATION UNITS
1.
Compliance Requirements
(a)
For each glycol dehydration unit constructed under an Authorization to Use GP-5 approved by the Department
prior to February 2, 2013, with:
(i)
A total uncontrolled potential VOC emission rate greater than 10 tpy the owner or operator shall:
(A)
Control VOC emissions from the glycol dehydrator still vent stream by at least 85% with a
condenser, enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning device
approved by the Department that meets the applicable requirements in Section N;
and
(B)
Meet the requirements of (d) and (e) below.
(ii)
A total uncontrolled potential VOC emission rate less than or equal to 10 tpy, the owner or operator shall:
(A)
Meet the requirements of (d) and (e) below.
(B)
In the event that (d) is not met, the owner or operator must control VOC emissions in accordance
with (a)(i)(A) above.
(b)
For each glycol dehydration unit constructed on or after February 2, 2013, but prior to (effective date of GP-5),
with:
(i)
A total uncontrolled potential VOC emission rate of greater than 5 tpy, the owner or operator shall:
(A)
Control VOC emissions from the glycol dehydrator still vent stream by at least 95% with a
condenser, enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning device
approved by the Department that meets the applicable requirements in Section N;
and
(B)
Meet the requirements of (d) and (e) below.
(ii)
A total uncontrolled potential VOC emission rate of less than or equal to 5 tpy, the owner or operator
shall:
(A)
Meet the requirements of (d) and (e) below.
(B)
In the event that (d) is not met, the owner or operator must control VOC emissions in accordance
with (b)(i)(A) above.
(c)
For each glycol dehydrator constructed on or after (effective date of GP-5), with:
(i)
An uncontrolled methane emission rate of 200 tpy or greater, a total uncontrolled VOC emission rate of
2.7 tpy or greater, an uncontrolled single HAP emission rate of 0.5 tpy or greater, or a total uncontrolled
HAP emission rate of 1.0 tpy or greater, the owner or operator shall:
(A)
Control methane, VOC, and HAP emissions from the glycol dehydrator still vent stream by at least
98% with a condenser, enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning
device approved by the Department that meets the applicable requirements in Section N;
and
(B)
Meet the requirements of (d) and (e) below.
(ii)
An uncontrolled methane emission rate of less than 200 tpy, a total uncontrolled VOC emission rate of
less than 2.7 tpy, an uncontrolled single HAP emission rate of less than 0.5 tpy, and a total uncontrolled
HAP emission rate of less than 1.0 tpy, the owner or operator shall:
(A)
Meet the requirements of (d) and (e) below.
(B)
In the event that (d) is not met, the owner or operator must control methane and VOC emissions in
accordance with (c)(i)(A) above.
(d)
The owner or operator shall meet the malodor requirements of Section A Condition 9(c)(iii).
(e)
To demonstrate compliance, the owner or operator shall submit the required notifications and reports and
maintain the required records.

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(f)
Associated equipment, such as reboilers (Section C), flash tanks (Section I), controllers (Section L), pumps
(Section M), and fugitive emissions components (Section K) are subject to the requirements of their respective
Sections.
(g)
If any glycol dehydration unit uses triethylene glycol for the dehydration process, has a natural gas throughput
greater than 3 MMscf/d,
and
emits more than 1 tpy of benzene, the owner or operator must:
(i)
Determine the natural gas throughput by either:
(A)
Installing and operating a monitoring instrument that directly measures natural gas flowrate to the
glycol dehydration unit with an accuracy of plus or minus 2% or better and then converting 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;
or
(B)
Documenting to the Department’s satisfaction the actual annual average natural gas flowrate to
the glycol dehydration unit.
(ii)
Determine the actual average benzene or BTEX emissions by either:
(A)
Using GRI-GLYCalc Version 3.0 or higher with the inputs to the model representative of actual
operating conditions of the glycol dehydration unit;
or
(B)
Determining an average mass rate of benzene or BTEX emissions using direct measurement
using methods in 40 CFR §63.772(a)(1)(i) or an alternative method according to 40 CFR §63.7(f).
(iii)
If the glycol dehydration unit is located at a facility located within an urbanized area plus offset or urban
cluster boundary, the owner or operator shall:
(A)
Connect the process vent to a control device through a closed-vent system designed and operated
in accordance with the applicable requirements of Section N such that:
(1)
Benzene emissions are reduced below 1 tpy;
or
(2)
Total organic compounds or total HAP are reduced by at least 95%.
(iv)
If the glycol dehydration unit is located at a facility that is not within an urbanized area plus offset or
urban cluster boundary, the owner or operator shall:
(A)
Determine the optimum glycol circulation rate using the equation:
L
OPT
= 1.15 ∗
3.0 gal TEG
lb H
2
O
∗ (
F ∗ (I − O)
24
h
d
)
Where:
L
OPT
is the Optimal Circulation Rate in gal/h
F is the Gas Flowrate in MMscf/d
I is the Inlet Water Content in lb/MMscf
O is the Outlet Water Content in lb/MMscf
3.0 is the industry accepted rule of thumb for a TEG-to-water ratio in gal TEG/lb H
2
O
1.15 is an adjustment factor included for a margin of safety.
(B)
Operate the triethylene glycol dehydration unit such that the actual glycol circulation rate does not
exceed the calculated optimum glycol circulation rate.
(C)
Determine an alternate circulation rate using GRI-GLYCalc computer software or other method
approved by the Department if the optimum glycol circulation rate calculated in (g)(iv)(A) above is
not adequate to meet the sales gas specification for moisture content.
2.
Notification Requirements
Notifications for each glycol dehydration unit must be done in accordance with Section A Condition 10(b) through (d).
If an alternate circulation rate is required as in Condition 1(g)(iv)(C) above, the determination must be submitted to
the Air Program Manager of the appropriate DEP Regional Office at least 5 days prior to altering the circulation rate.
3.
Recordkeeping Requirements
For each glycol dehydration unit, the owner or operator shall maintain the following records in accordance with
Section A Condition 11, including information on:
(a)
The location of the glycol dehydration unit;

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(b)
The actual daily throughput of natural gas;
(c)
The calculation for the optimum glycol circulation rate or the alternative glycol circulation rate,
if applicable
;
(d)
The determination of the actual average benzene or BTEX emissions,
if applicable
;
(e)
The actual daily glycol circulation rate;
(f)
The emissions calculations for each glycol dehydrator;
and
(g)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each glycol dehydration unit
operated during the reporting period shall include:
(a)
The records of VOC emissions calculated using GRI-GLYCalc computer software or an alternative method as
approved by the Department;
(b)
The records of the actual daily throughput of natural gas;
(c)
The records of the actual daily glycol circulation rate;
(d)
The records of the optimum or alternative glycol circulation rate,
if applicable
;
(e)
The records of the determination of the actual average benzene or BTEX emissions,
if applicable
;
(f)
A statement that the applicable cover, closed vent system, and/or control device requirements have been met;
and
(g)
The records of any deviations and malfunctions.
The emissions from each glycol dehydration unit operated during the reporting period must be included in the
emissions inventory report of Section A Condition 12(d).
SECTION E. STATIONARY NATURAL GAS-FIRED SPARK IGNITION INTERNAL COMBUSTION ENGINES
1.
Compliance Requirements
(a)
For each natural gas-fired spark ignition internal combustion engine constructed under an Authorization to Use
GP-5 approved by the Department prior to February 2, 2013, the owner or operator shall:
(i)
Operate or equip the engine with air cleaning devices to meet the following emission levels:
(A)
NO
X
(as NO
2
) of 2.00 g/bhp-h while operating at rated bhp and speed;
(B)
NMNEHC (as propane), excluding formaldehyde, of 2.00 g/bhp-h while operating at rated bhp and
speed;
and
(C)
CO of 2.00 g/bhp-h while operating at rated bhp and speed.
(ii)
Ensure that at operating conditions less than rated capacity, the engine shall on a lb/h basis emit no
more than it would emit at rated bhp and speed.
(iii)
Ensure the engine meets the requirements of (d) below.
(b)
For each natural gas-fired spark ignition internal combustion engine constructed under an Authorization to Use
GP-5 approved by the Department on or after February 2, 2013, but prior to (effective date of GP-5), the owner
or operator shall:
(i)
Ensure the engine does not exceed the emissions standards specified in the following table:

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Engine Type
Rated
bhp
NO
X
CO
NMNEHC
(as propane)
excluding
HCHO
HCHO
Lean-Burn
≤100
2.00 g/bhp-h
2.00 g/bhp-h
-
-
Lean-Burn
100<
ER
≤500
1.00 g/bhp-h
2.00 g/bhp-h
0.70 g/bhp-h
-
Lean-Burn
500<
0.50 g/bhp-h
47 ppmvd @
15% O
2
or
93% reduction
0.25 g/bhp-h
0.05 g/bhp-h
Rich-Burn
≤100
2.00 g/bhp-g
2.00 g/bhp-h
-
-
Rich-Burn
100<
ER
≤500
0.25 g/bhp-h
0.30 g/bhp-h
0.20 g/bhp-h
-
Rich-Burn
>500
0.20 g/bhp-h
0.30 g/bhp-h
0.20 g/bhp-h
2.7 ppmvd @
15% O
2
or
76% reduction
(ii)
Ensure the engine meets the requirements of (d) below.
(c)
For each natural gas-fired spark ignition internal combustion engine constructed on or after (effective date of
GP-5), the owner or operator shall:
(i)
Ensure the engine does not exceed the emission standards specified in the following table:
Engine Type
Rated
bhp
NO
X
CO
NMNEHC
(as propane)
excluding
HCHO
HCHO
Lean-Burn
<100
1.00 g/bhp-h
2.00 g/bhp-h
0.70 g/bhp-h
-
Lean-Burn
100≤
ER
≤500
1.00 g/bhp-h
0.70 g/bhp-h
0.30 g/bhp-h
-
Lean-Burn
500<
ER
<1,875
0.50 g/bhp-h
0.35 g/bhp-h
0.25 g/bhp-h
0.05 g/bhp-h
Lean-Burn
1,875≤
ER
<3,000
0.35 g/bhp-h
Uncontrolled
or
0.05 g/bhp-h
with Control
0.25 g/bhp-h
0.25 g/bhp-h
0.05 g/bhp-h
Lean-Burn
≥ 3,000
0.05 g/bhp-h
0.25 g/bhp-h
0.25 g/bhp-h
0.05 g/bhp-h
Rich-Burn
<100
0.60 g/bhp-h
0.60 g/bhp-h
0.10 g/bhp-h
Rich-Burn
100≤
ER
≤500
0.25 g/bhp-h
0.30 g/bhp-h
0.20 g/bhp-h
-
Rich-Burn
>500
0.20 g/bhp-h
0.30 g/bhp-h
0.20 g/bhp-h
2.7 ppmvd @
15% O
2
or
76% reduction
(ii)
Ensure that for engines that control NO
X
emissions with a control technology that uses ammonia or urea
as a reagent, the exhaust ammonia slip is limited to 5 ppmvd or less corrected to 15% O
2
.
(iii)
Ensure the engine meets the requirements of (d) below.
(d)
The owner or operator of the engine shall also:

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(i)
Comply with the requirements for engines constructed (as defined in 40 CFR Part 63, Subpart ZZZZ)
prior to June 12, 2006, in the following table:
Engine Category
Oil and
Filter
Change
Spark Plug
Inspection,
Plugs Replaced as
Necessary
Hose Inspection,
Hoses Replaced as
Necessary
Emergency SI RICE;
4SRB and 4SLB >500
hp that operate ≤ 24
hours per year
500 hours or
annually
1,000 hours or
annually
500 hours or annually
4SRB and 4SLB > 500
hp in remote locations
2,160 hours
or annually
2,160 hours or
annually
2,160 hours or
annually
4SLB > 500 hp
Install an oxidation catalyst to reduce HAP emissions
and
either a CPMS to monitor the catalyst inlet temperature
or
equipment to shut down the engine if the catalyst inlet
temperature exceeds 1350°F
4SRB > 500 hp
Install NSCR to reduce HAP emissions
and
either a CPMS
to monitor the catalyst inlet temperature
or
equipment to
shut down the engine if the catalyst inlet temperature
exceeds 1250°F
4SRB and 4SLB ≤ 500
hp
1,440 hours
or annually
1,440 hours or
annually
1,440 hours or
annually
2SLB
4,320 hours
or annually
4,320 hours or
annually
4,320 hours or
annually
(A)
Where remote is defined as in 40 CFR Part 63, Subpart ZZZZ.
(ii)
Ensure the engine meets the visible emissions standards, as determined by the methods described in 25
Pa. Code §123.43, by not exceeding the following limitations:
(A)
Equal to or greater than 10% for a period or periods aggregating more than three minutes in any
one hour;
and
(B)
Equal to or greater than 30% at any time
(iii)
Install, operate, and maintain a non-resettable hour meter;
(iv)
Install, operate, and maintain a fuel flow meter;
(v)
Limit the engine’s time spent at idle during startup or shutdown to a period appropriate for the operation
of the engine and air pollution control equipment consistent with good air pollution control practices, not
to exceed 30 minutes, during which time the emissions standards in (a) through (c) do not apply.
(vi)
Conduct performance tests and periodic monitoring for the engine as detailed in Condition 5 of this
section on the following schedule:
Engine Size
Initial Compliance
Performance Test
Continuous Compliance
Performance Test
Periodic
Monitoring
<100 hp
None Required
None Required
100 hp ≤ ER ≤ 500
hp
Within 180 days of
startup of the engine
Within 180 days of each
reauthorization
Every 2,500 hours
of operation
>500 hp
Within 180 days of
startup of the engine
Every 8,760 hours of operation
or
every three years
and
within 180 days of each
reauthorization
Every 2,500 hours
of operation
> 500 hp and
subject to (d)(i)
Not Applicable
Every year
Every 2,500 hours
of operation
(A)
For an engine greater than or equal to 100 hp and less than or equal to 500 hp, if the engine is
certified by the manufacturer in accordance with 40 CFR Part 60, Subpart JJJJ and the owner or
operator operates and maintains the engine in accordance with the manufacturer’s instructions,
the performance testing requirements are waived.

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(B)
For an engine greater than 500 hp, if the engine is certified by the manufacturer in accordance with
40 CFR Part 60, Subpart JJJJ and the owner or operator operates and maintains the engine in
accordance with the manufacturer’s instructions, the continuous compliance performance testing
requirements every 8,760 hours of operation or every three years are waived.
2.
Notification Requirements
Notifications for each natural gas-fired spark ignition engine must be done in accordance with Section A Condition
10(b) through (d). Notifications for performance testing of each natural gas-fired spark ignition engine must be done
in accordance with Section A Condition 13(f) and (g).
3.
Recordkeeping Requirements
For each engine, the owner or operator shall maintain the following records in accordance with Section A Condition
11, including information on:
(a)
The location of each engine;
(b)
The GP-5 authorization number and the date each engine was authorized for use;
(c)
The make, model, and serial number of each engine;
(d)
The number of hours per month that each engine operated;
(e)
The amount of fuel that is used per month in each engine;
(f)
Either a copy of the manufacturer’s maintenance instructions
or
an alternative maintenance plan;
(g)
Records of maintenance conducted on each engine and any installed air pollution control devices;
(h)
A copy of the manufacturer’s engine certification or vendor guarantees;
(i)
Records of all notifications as detailed in Condition 2 above;
(j)
The results of each periodic monitoring;
(k)
The summary for each complete test report described in Section A Condition 13(h);
(l)
The site-specific monitoring plan for a CPMS,
if applicable
;
(m)
The data collected from a CPMS,
if applicable
;
(n)
The emissions calculations for each engine;
and
(o)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each engine operated during the
reporting period shall include:
(a)
The records of the number of hours each engine operated;
(b)
The records of the actual fuel usage for each engine;
(c)
The records of maintenance conducted on each engine and any installed air pollution control devices;
(d)
The results of each periodic monitoring conducted;
(e)
The summary for each complete test report described in Section A Condition 13(h) conducted;
(f)
The results of the CPMS performance evaluation, if one is installed;
and
(g)
The records of any deviations and malfunctions.
The emissions from each natural gas-fired spark ignition internal combustion engine operated during the reporting
period must be included in the emissions inventory report of Section A Condition 12(d).
5.
Performance Testing Requirements
(a)
When conducting a performance test for an engine, the owner or operator may follow the procedure detailed in
(b) below and forego the need to submit the test protocol described in Section A Condition 13(e). If the owner
or operator decides to use other methods, such as those outlined in 40 CFR Part 60 Subpart JJJJ or 40 CFR
Part 63 Subpart ZZZZ, they must submit the test protocol described in Section A. Condition 13 (e) for review
and approval.
(b)
Standardized Performance Test Procedure.
(i)
Conduct three test runs of at least one hour duration within 10% of the highest achievable load.

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(ii)
Select the sampling port location and the number and location of traverse points at the exhaust using
40 CFR Part 60, Appendix A-1, Method 1 or 1A depending on stack diameter, or the sampling points
selected according to 40 CFR Part 60, Appendix A-4, Method 7E Section 8.1.2.
(iii)
Determine the effluent characteristics by either:
(A)
Calculating the exhaust flow in accordance with 40 CFR Part 60, Appendix A-7, Method 19 and
measuring the O
2
concentration using 40 CFR Part 60, Appendix A-2, Method 3A;
or
(B)
By measuring:
(1)
The flow velocity, stack temperature, static pressure, and barometric pressure using 40 CFR
Part 60, Appendix A-1, Method 2 or 2C depending on stack diameter;
(2)
The gas density using 40 CFR Part 60, Appendix A-2, Method 3A;
and
(3)
The moisture content using 40 CFR Part 60, Appendix A-3, Method 4.
(iv)
Simultaneous to the determination of the O
2
concentration in (iii)(B) above, determine:
(A)
The NO
X
concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 7E;
(B)
The CO concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 10;
(C)
The NMNEHC concentration, as propane, excluding formaldehyde of the exhaust gas using
40 CFR Part 60, Appendix A-7, Method 25A to determine the THC, 40 CFR Part 60, Appendix A-6,
Method 18 to determine the methane and ethane concentration and then subtracting the methane
and ethane concentrations from the THC;
and
(D)
The formaldehyde concentration of the exhaust gas,
if applicable
, using 40 CFR Part 63,
Appendix A, Method 323.
(c)
If at any time the owner or operator operates the engine in excess of the highest achievable load plus 10%, the
owner or operator must perform a stack test within 180 days from the anomalous operation.
6.
Periodic Monitoring Requirements
(a)
When conducting periodic monitoring on an engine, the owner or operator may follow the procedures in (b)
below. If the owner or operator decides to deviate from those procedures, they must submit a request to use
an alternate procedure, in writing, at least 60 days prior to performing the periodic monitoring. In the alternate
procedure request, the owner or operator must demonstrate the alternate procedure’s equivalence to the
standard procedure to the satisfaction of the Division of Source Testing and Monitoring.
(b)
Standardized Periodic Monitoring Procedure.
(i)
Conduct three test runs of at least 20 minutes duration within 10% of the highest achievable load.
(ii)
Determine NO
X
and CO emissions concentrations in the exhaust with an electro-chemical cell portable
gas analyzer used and maintained in accordance with the manufacturer’s specifications and following the
procedures specified in ASTM D6522.
(iii)
If the measured NO
X
or CO emissions concentrations are within the margin of instrument error
or
in
exceedance of the emissions limit, the owner or operator must perform a stack test within 180 days of
the periodic monitoring.
(c)
The 2,500 hours of operation count resets after any performance test performed in accordance with Condition
5 above.
(d)
For engines constructed (as defined in that subpart) prior to June 12, 2006, that installed a CPMS to monitor
the catalyst inlet temperature, the owner or operator must install, operate, and maintain the CPMS according to
40 CFR §63.6625(b)(1) through (6).
SECTION F. STATIONARY NATURAL GAS-FIRED COMBUSTION TURBINES
1.
Compliance Requirements
(a)
For each natural gas-fired combustion turbine constructed prior to February 2, 2013, the owner or operator
shall abide by the terms and conditions of the applicable plan approval or operating permit under which they
were authorized.
(b)
For each natural gas-fired combustion turbine constructed under an Authorization to Use GP-5 approved by
the Department on or after February 2, 2013, but prior to (effective date of GP-5), the owner or operator shall:
(i)
Ensure the turbine does not exceed the emissions standards specified in the following table:

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Turbine
Rating
(bhp)
NO
X
(ppmdv @
15% O
2
)
CO
(ppmdv @
15% O
2
)
NMNEHC
(as propane)
(ppmdv @
15% O
2
)
Total PM
(lbs/MMBtu)
1,000≤
TR
<5,000
25.00
25.00
9.00
0.030
5,000≤
TR
<15,000
15.00
25.00
9.00
0.030
≥15,000
15.00
10.00
or
93% reduction
5.00
or
50% reduction
0.030
(ii)
Ensure the turbine meets the requirements of (d) below.
(c)
For each natural gas-fired combustion turbine constructed on or after (effective date of GP-5) the owner or
operator shall:
(i)
Ensure the turbine does not exceed the emission standards specified in the following table:
Turbine
Rating
(bhp)
NO
X
(ppmdv @
15% O
2
)
CO
(ppmdv @
15% O
2
)
NMNEHC
(as propane)
(ppmdv @
15% O
2
)
Total PM
(lbs/MMBtu)
1,000≤
TR
<5,000
25.00
25.00
9.00
0.03
5,000≤
TR
<15,900
15.00
Uncontrolled
or 2.50 with
Control
10.00
Uncontrolled or
1.75 with
Control
5.00
Uncontrolled or
4.50 with
Control
0.03
≥15,900
9.00
Uncontrolled
or 1.50 with
Control
10.00
Uncontrolled or
1.75 with
Control
5.00
Uncontrolled or
4.50 with
Control
0.03
(ii)
Ensure that for turbines that control NO
X
emissions with a control technology that uses ammonia or urea
as a reagent, the exhaust ammonia slip is limited to 5 ppmvd or less corrected to 15% O
2
.
(iii)
Ensure the turbine meets the requirements of (d) below.
(d)
The owner or operator of the turbine shall also:
(i)
Ensure the turbine meets the visible emissions standards, as determined by the methods described in
25 Pa. Code §123.43, by not exceeding the following limitations:
(A)
Equal to or greater than 10% for a period or periods aggregating more than three minutes in any
one hour;
and
(B)
Equal to or greater than 30% at any time.
(ii)
Install, operate, and maintain a non-resettable hour meter.
(iii)
Install, operate, and maintain a fuel flow meter.
(iv)
Limit the turbine’s time spent at idle during startup or shutdown to a period appropriate for the operation
of the turbine and air pollution control equipment consistent with good air pollution control practices, not
to exceed 30 minutes, during which time the emissions standards in (a) through (c) do not apply.
(v)
Conduct performance tests for the turbine as detailed in Condition 5 below within 180 days of initial
startup and within 180 days of reauthorization of this General Permit and periodic monitoring for the
turbine every 2,500 hours of operation. In addition, there is an annual performance test requirement for
turbines that control NO
X
using methods other than water or steam injection, although it may be waived if
the owner or operator installs a continuous monitoring system as detailed in Condition 6(d) below.

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2.
Notification Requirements
Notifications for each natural-gas fired combustion turbine must be done in accordance with Section A Condition
10(b) through (d). Notifications for performance testing of each natural-gas fired combustion turbine must be done in
accordance with Section A Condition 13(f) and (g).
3.
Recordkeeping Requirements
For each turbine, the owner or operator shall maintain the following records in accordance with Section A Condition
11, including information on:
(a)
The location of each turbine;
(b)
The GP-5 authorization number and the date each turbine was authorized for use;
(c)
The make, model, and serial number of each turbine;
(d)
The number of hours per month that each turbine operated;
(e)
The amount of fuel that is used per month in each turbine;
(f)
A copy of the manufacturer’s maintenance instructions
or
an alternative maintenance plan;
(g)
Records of maintenance conducted on each turbine and any installed air pollution control devices;
(h)
A copy of the vendor’s emission guarantees;
(i)
Records of all notifications as detailed in Condition 2 above;
(j)
The results of each periodic monitoring;
(k)
The summary for each complete test report described in Section A Condition 13(h);
(l)
Representative fuel sampling data;
(m)
The site-specific monitoring plan for a CPMS, if one is installed;
(n)
The data collected from a CPMS, if one is installed;
(o)
The results of all compliance calculations;
(p)
The emissions calculations for each turbine;
and
(q)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each turbine operated during the
reporting period shall include:
(a)
The records of the number of hours each turbine operated;
(b)
The records of the actual fuel usage for each turbine;
(c)
The records of maintenance conducted on each turbine and any installed air pollution control devices;
(d)
The results of each periodic monitoring conducted;
(e)
The summary for each complete test report described in Section A Condition 13(h) conducted;
(f)
The results of the CPMS performance evaluation, if one is installed
(g)
The records of all compliance calculations;
and
(h)
The records of any deviations and malfunctions.
The emissions from each natural gas-fired combustion turbine operated during the reporting period must be included
in the emissions inventory report of Section A Condition 12(d).
5.
Performance Testing Requirements
(a)
When conducting a performance test for a turbine, the owner or operator may follow the procedure detailed in
(b) below and forego the need to submit the test protocol described in Section A Condition 13(e). If the owner
or operator decides to use other methods, such as those outlined in 40 CFR Part 60 Subpart KKKK, they must
submit the test protocol described in Section A Condition 13(e) for review and approval.
(b)
Standardized Performance Test Procedure.
(i)
Conduct three test runs of at least one hour duration within 25% of the highest achievable load.

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(ii)
Select the sampling port location and the number and location of traverse points at the exhaust using
40 CFR Part 60, Appendix A-1, Method 1 or 1A depending on stack diameter, or the sampling points
selected in accordance with 40 CFR Part 60, Appendix A-4, Method 7E, Section 8.1.2.
(iii)
Determine the effluent characteristics by either:
(A)
Calculating the exhaust flow in accordance with 40 CFR Part 60, Appendix A-7, Method 19 and
measuring the O
2
concentration using 40 CFR Part 60, Appendix A-2, Method 3A;
or
(B)
By measuring:
(1)
The flow velocity, stack temperature, static pressure, and barometric pressure using 40 CFR
Part 60, Appendix A-1, Method 2 or 2C depending on stack diameter;
(2)
The gas density using 40 CFR Part 60, Appendix A-2, Method 3A;
and
(3)
The moisture content using 40 CFR Part 60, Appendix A-3, Method 4.
(iv)
Simultaneous to the determination of the O
2
concentration in (iii)(B) above, determine:
(A)
The NO
X
concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 7E;
(B)
The CO concentration of the exhaust gas using 40 CFR Part 60, Appendix A-4, Method 10;
(C)
The NMNEHC concentration, as propane, of the exhaust gas using 40 CFR Part 60, Appendix A-7,
Method 25A to determine the THC, 40 CFR Part 60, Appendix A-6 and Method 18 to determine
the methane and ethane concentration and then subtracting the methane and ethane
concentrations from the THC;
and
(D)
The total PM using 40 CFR Part 60, Appendix A-3, Method 5 for filterable PM and 40 CFR Part 51,
Appendix M, Method 202 for condensable PM.
(c)
If at any time the owner or operator operates the engine in excess of the highest achievable load plus 25%, the
owner or operator must perform a stack test within 180 days from the anomalous operation.
6.
Periodic Monitoring Requirements
(a)
When conducting periodic monitoring on a turbine, the owner or operator may follow the procedures in (b)
below. If the owner or operator decides to deviate from those procedures, they must submit a request to use
an alternate procedure, in writing, at least 60 days prior to performing the periodic monitoring. In the alternate
procedure request, the owner or operator must demonstrate the alternate procedure’s equivalence to the
standard procedure to the satisfaction of the Division of Source Testing and Monitoring.
(b)
Standardized Periodic Monitoring Procedure.
(i)
Conduct three test runs of at least 20 minutes duration within 25% of the highest achievable load.
(ii)
Determine NO
X
and CO emissions concentrations in the exhaust with an electro-chemical cell portable
gas analyzer used and maintained in accordance with the manufacturer’s specifications and following the
procedures specified in ASTM D6522.
(iii)
If the measured NO
X
or CO emissions concentrations are within the margin of instrument error
or
in
exceedance of the emissions limit, the owner or operator must perform a stack test within 180 days of
the periodic monitoring.
(c)
The 2,500 hours of operation count resets after any performance test performed in accordance with Condition
5 above.
(d)
For turbines that control NO
X
emissions:
(i)
Using water or steam injection, the owner or operator may either install, calibrate, maintain, and operate:
(A)
A CEMS that meets the following criteria:
(1)
Consists of a NO
X
monitor and a diluent gas monitor (either O
2
or CO
2
) that is installed and
certified in accordance with 40 CFR Part 60, Appendix B, Performance Specification 2 to
determine the hourly average NO
X
emission rate in ppm;
(2)
During each full unit operating hour, both the NO
X
and diluent monitors must complete a
minimum of one cycle of operation for each 15-minute quadrant of the hour to validate the
hour;
(3)
Calculate the 4-hour rolling average NO
X
emission rate and then correct to 15% O
2
;
(4)
The owner or operator shall develop a quality assurance and quality control (QA/QC) plan
for any installed monitoring equipment;
or

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(B)
A CPMS that monitors and records the fuel consumption and the water-to-fuel or steam-to-fuel
ratio in accordance with (iv) below and then calculate the 4-hour rolling average water-to-fuel or
steam-to-fuel ratio.
(ii)
Using methods other than water or steam injection, the owner or operator may either install, calibrate,
maintain, and operate:
(A)
A CEMS that meets the criteria of (d)(i)(A) above;
or
(B)
A CPMS that monitors the parameters for:
(1)
A diffusion flame turbine without add-on SCR controls that are indicative of the turbine’s NO
X
formation characteristics in accordance with (iv) below;
(2)
Any lean premix turbine that are indicative of the turbine’s operation in low-NO
X
mode in
accordance with (iv) below;
or
(3)
Any turbine that uses SCR to reduce NO
X
emissions that are indicative of the proper
operation of the emissions controls in accordance with (iv) below;
and
(4)
Calculate the 4-hour rolling average for each monitored parameter.
(iii)
The owner or operator that installs, calibrates, maintains, and operates a CPMS shall develop a
site-specific parameter monitoring plan which must:
(A)
Include the indicators to be monitored and show there is a significant relationship to emissions and
proper operation of the NO
X
emission controls;
(B)
Establish designated conditions or ranges of the indicators in accordance with (iv) below;
(C)
Explain the process that will make certain that the data obtained is representative of the emissions
or parameters being monitored;
(D)
Describe the QA/QC practices that will ensure the continuing validity of the data;
(E)
Describe the frequency of the monitoring and data collection procedures;
and
(F)
Include the basis for determining the parameter ranges in accordance with (A) through (E) above,
including justification if chosen ranges differ from the manufacturer’s recommendation.
(iv)
During the initial performance test, the owner or operator shall determine the value ranges for the
applicable parameters and may supplement the performance test data with engineering analyses, design
specifications, manufacturer’s recommendations, and other relevant information to define the parametric
ranges more precisely.
(v)
Excess emissions and monitor downtime shall be recorded as a deviation and submitted with the annual
report required in Section A Condition 12(c).
SECTION G. RECIPROCATING COMPRESSORS
1.
Compliance Requirements
(a)
The owner or operator of a reciprocating compressor constructed on or after August 23, 2011, shall either:
(i)
Replace the reciprocating compressor rod packing either:
(A)
On or before 26,000 hours of operation from the initial startup date or most recent rod packing
replacement;
or
(B)
Prior to 36 months from the initial startup date of the reciprocating compressor or the date of the
most recent rod packing replacement;
or
(ii)
Collect the methane, VOC, and HAP emissions from the rod packing using a collection system that
operates under negative pressure and routes the emissions to a process through a closed vent system
that meets the applicable requirements of Section N.
(b)
To demonstrate compliance, the owner or operator must submit the required notifications and reports and
maintain the required records.
2.
Notification Requirements
Notifications for each reciprocating compressor must be done in accordance with Section A Condition 10(b) through
(d). In addition, the owner or operator must submit notification of any scheduled blowdown or venting for each
reciprocating compressor in accordance with Section A Condition 10(e).

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3.
Recordkeeping Requirements
For each reciprocating compressor, the owner or operator shall maintain the following records in accordance with
Section A Condition 11, including information on:
(a)
The location of the reciprocating compressor;
(b)
The date and time of the initial startup of the reciprocating compressor;
(c)
The date and time of the most recent rod packing replacement;
(d)
The cumulative number of hours of operation or number of months since the initial startup of the reciprocating
compressor or most recent rod packing replacement;
(e)
The date and time of installation of a rod packing emissions collection system and closed vent system;
(f)
The date, time, and duration of any blowdown or venting of the reciprocating compressor;
(g)
The emissions calculation for each reciprocating compressor;
and
(h)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each reciprocating compressor
operated during the reporting period shall include:
(a)
Either the records of the cumulative number of hours of operation or number of months since the initial startup
of the reciprocating compressor or most recent packing replacement;
or
a statement that emissions from the
rod packing are being routed to a process through a closed vent system under negative pressure;
and
(b)
The records of deviations and malfunctions.
The emissions from each reciprocating compressor operating during the reporting period must be included in the
emissions inventory report of Section A Condition 12(d), including the emissions from scheduled and unscheduled
blowdowns.
SECTION H. CENTRIFUGAL COMPRESSORS
1. Compliance Requirements
(a)
For a centrifugal compressor constructed on or after August 23, 2011, but prior to (effective date of GP-5), the
owner or operator shall:
(i)
For a wet seal compressor:
(A)
Equip the wet seal fluid degassing system with a cover and route all vapor through a closed vent
system to a control device that reduces VOC emissions by 95% or more by meeting the applicable
control, cover, and closed vent system requirements of Section N Condition 1(a) or (b), (e), and (f)
or any alternative method approved by the Department;
and
(B)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(ii)
For a dry seal centrifugal compressor demonstrate compliance by submitting the notifications of
Condition 2, keeping the records of Condition 3(a) and (e) through (g), and submitting the reports of
Condition 4.
(b)
For a centrifugal compressor constructed on or after (effective date of GP-5), the owner or operator shall:
(i)
For a wet seal compressor:
(A)
Equip the wet seal fluid degassing system with a cover and route all vapor through a closed vent
system to a control device that reduces methane, VOC, and HAP emissions by 98% or more by
meeting the applicable control, cover, and closed vent system requirements of Section N Condition
1(a) or (b), (e), and (f) or any alternative method approved by the Department;
and
(B)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.

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(ii)
For a dry seal centrifugal compressor demonstrate compliance by submitting the notifications of
Condition 2, keeping the records of Condition 3(a) and (e) through (g), and submitting the reports of
Condition 4.
2.
Notification Requirements
Notifications for each centrifugal compressor must be done in accordance with Section A Condition 10(b) through (d).
In addition, the owner or operator must submit notification of any scheduled blowdown or venting for each centrifugal
compressor in accordance with Section A Condition 10(e).
3.
Recordkeeping Requirements
For each centrifugal compressor, the owner or operator shall maintain the following records in accordance with
Section A Condition 11, including information on:
(a)
The location of the centrifugal compressor;
(b)
The control device specifications as detailed in Section N Condition 3(a) through (d),
if applicable
;
(c)
The cover inspection required as detailed in Section N Condition 3(e),
if applicable
;
(d)
The closed vent system inspection required as detailed in Section N Condition 3(f),
if applicable
;
(e)
The date, time, and duration of any blowdown or venting of the centrifugal compressor;
(f)
The emissions calculation for each centrifugal compressor;
and
(g)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each centrifugal compressor
operated during the reporting period shall include:
(a)
An identification of each centrifugal compressor constructed;
(b)
A statement that the applicable cover, closed vent system, and/or control device requirements have been met;
and
(c)
The records of deviations and malfunctions.
The emissions from each centrifugal compressor operating during the reporting period must be included in the
emissions inventory report of Section A Condition 12(d), including the emissions from scheduled and unscheduled
blowdowns.
SECTION I. STORAGE VESSELS
1. Compliance Requirements
(a)
For each storage vessel constructed on or after August 23, 2011, but prior to (effective date of GP-5), that:
(i)
Routes all vapor through a vapor recovery unit, the owner or operator shall:
(A)
Meet the applicable cover and closed vent system requirements in Section N Condition 1(e) and
(f);
and
(B)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(ii)
Has a total uncontrolled potential VOC emission rate greater than or equal to 6.0 tpy, the owner or
operator shall either:
(A)
Equip the storage vessel with a cover and route all vapor through a closed vent system to a control
device that reduces VOC emissions by 95% or more by meeting the applicable control, cover, and
closed vent system requirements of Section N Condition 1(a) or (b), (e), and (f);
(B)
Install a floating roof which meets the applicable requirements in Section N. Condition 1(c) or (d);
or
(C)
Maintain the actual uncontrolled VOC emission rate at less than 4.0 tpy as determined monthly,
based on the average throughput for the month and meet the control requirement of (A) above
within 30 days of the actual uncontrolled VOC emission rate equals or exceeds 4.0 tpy;
and

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(D)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(b)
For each storage vessel constructed on or after (effective date of GP-5), with:
(i)
An uncontrolled methane emission rate of 200 tpy or greater, a total uncontrolled VOC emission rate of
2.7 tpy or greater, an uncontrolled single HAP emission rate of 0.5 tpy or greater, or a total uncontrolled
HAP emission rate of 1.0 tpy or greater, the owner or operator shall:
(A)
Equip the storage vessel with a cover and route all vapor through a closed vent system to a control
device that reduces methane, VOC, and HAP emissions by 98% or more by meeting the
applicable control, cover, and closed vent system requirements of Section N Condition 1(a)
through (f) or any alternative method approved by the Department;
and
(B)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(ii)
An uncontrolled methane emission rate of less than 200 tpy, a total uncontrolled VOC emission rate of
less than 2.7 tpy, an uncontrolled single HAP emission rate of less than 0.5 tpy, and a total uncontrolled
HAP emission rate of less than 1.0 tpy, the owner or operator shall demonstrate compliance by
submitting the required notifications and reports and maintaining the required records.
(c)
Any storage vessel removed from service must be completely emptied and degassed such that the vessel no
longer contains crude oil, condensate, produced water, or intermediate hydrocarbon liquids. A storage vessel
with liquid left on walls, as bottom clingage, or in pools due to floor irregularity is considered to be completely
empty.
(d)
Any storage vessel returned to service must meet the applicable requirements above.
(e)
Any storage vessel with a capacity greater than or equal to 2,000 gallons and less than or equal to 40,000
gallons which contain VOCs with vapor pressure greater than 1.5 psia under actual storage conditions shall
have pressure relief valves which are maintained in good operating condition and which are set to release at
no less than 0.7 psig of pressure or 0.3 psig of vacuum or the highest possible pressure and vacuum in
accordance with state or local fire codes, the National Fire Prevention Association guidelines, or other national
consensus standards acceptable to the Department. When a VOC’s storage temperature is governed by
ambient weather conditions, the vapor pressure under actual storage conditions shall be determined using a
temperature which is representative of the average storage temperature for the hottest month of the year in
which storage takes place.
2.
Notification Requirements
Notifications for each storage vessel must be done in accordance with Section A Condition 10(b) through (d).
3.
Recordkeeping Requirements
For each storage vessel, the owner or operator shall maintain the following records in accordance with Section A
Condition 11, including information on:
(a)
The identification, location, and date of construction of each storage vessel;
(b)
The VOC potential to emit determination including identification of the model or calculation methodology used;
(c)
The actual uncontrolled VOC emissions determined on a monthly basis,
if applicable
;
(d)
The control device specifications as detailed in Section N Condition 3(a) through (d),
if applicable
;
(e)
The cover inspection required as detailed in Section N Condition 3(e),
if applicable
;
(f)
The closed vent system inspection required as detailed in Section N Condition 3(f),
if applicable
;
(g)
The date each storage vessel was removed from or returned to service;
(h)
The emissions calculation for each storage vessel which may be calculated using Department approved
methods such as direct measurement; modeling programs such as the most recent version of EPA TANKS,
ProMax, and API E&P Tanks; process simulation software such as HYSIM, HYSIS, WINSIM, and PROSIM; or
calculation methodologies such as the Vazquez-Beggs equation;
and
(i)
Records of deviations and malfunctions.

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4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each storage vessel operated during
the reporting period shall include:
(a)
The identification, location, and date of construction for each storage vessel constructed;
(b)
The records of the VOC potential to emit determination including identification of the model or calculation
methodology used for each storage vessel constructed;
(c)
The records of the date each storage vessel was removed from or returned to service;
(d)
The determination that the control efficiency is met or exceeded,
if applicable
;
(e)
A statement that the applicable cover, closed vent system, and/or control device requirements have been met;
and
(f)
The records of deviations and malfunctions.
The emissions from each storage vessel operating during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).
SECTION J. TANKER TRUCK LOAD-OUT OPERATIONS
1. Compliance Requirements
(a)
The owner or operator is required to use a vapor recovery load-out system that meets the closed vent system
requirements of Section N Condition 1(f) for all truck load-out operations.
(b)
Each tanker truck that is used to remove liquids from a storage vessel is required to have one of the following
annual leak tests:
(i)
A tanker truck that does not indicate more than 1” H
2
O pressure change within 5 minutes after being
pressurized to 18” H
2
O and after being depressurized to 6” H
2
O vacuum has passed a MACT-level test
and is assumed to have a collection efficiency of 99.2%.
(ii)
A tanker truck that does not indicate more than 3” H
2
O pressure change within 5 minutes after being
pressurized to 18” H
2
O and after being depressurized to 6” H
2
O vacuum has passed an NSPS-level test
and is assumed to have a collection efficiency of 98.7%.
(iii)
A tanker truck that has passed a leak test performed in accordance with 49 CFR §180.407 is accepted
as equivalent to an NSPS-level collection efficiency of 98.7%.
(iv)
A tanker truck that has passed a leak test performed in accordance with 40 CFR Part 60, Appendix A-8,
Method 27 is accepted as equivalent to an NSPS-level collection efficiency of 98.7%.
(c)
To demonstrate compliance, the owner or operator must submit the required notification and reports and
maintain the required records.
2.
Notification Requirements
Notifications for the construction of the vapor recovery load-out system must be done in accordance with Section A
Condition 10(b) through (d).
3.
Recordkeeping Requirements
For each tanker truck load-out operation, the owner or operator shall maintain the following records in accordance
with Section A Condition 11, including information on:
(a)
The identification, location, and date of construction of each vapor recovery load-out system;
(b)
Records of the entire fleet of tanker trucks that collect liquids from the facility, including the date of and rating of
each leak test;
(c)
Records of each tanker truck load-out operation including the identification of the tanker truck, the date and
time of the liquids load-out, and the type and volume of liquids loaded;
(d)
The closed vent system inspection records as detailed in Section N Condition 3(f);
(e)
The emissions calculation for each tanker truck load-out operation, taking into account the fugitive emissions
which escape due to the capture efficiency being less than 100%;
and
(f)
Records of deviations and malfunctions.

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4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each tanker truck load-out operation
during the reporting period shall include:
(a)
The identification, location, and date of construction for each vapor recovery load-out system constructed;
(b)
The records of each tanker truck load-out operation including the identification of the tanker truck, the date and
time of the liquids load-out, and the type and volume of liquids loaded;
(c)
A statement that the applicable cover and/or closed vent system requirements have been met;
and
(d)
The records of deviations and malfunctions.
The emissions from tanker truck load-out operations during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).
SECTION K. FUGITIVE EMISSIONS COMPONENTS
1. Compliance Requirements
(a)
No later than 30 days after an emission source commences operation, and at least monthly thereafter, the
owner or operator of a facility shall conduct an AVO inspection.
(b)
No later than 60 days after initial startup, and quarterly thereafter, the owner or operator shall conduct an
LDAR program using either an OGI camera, a gas leak detector that meets the requirements of 40 CFR Part
60, Appendix A-7, Method 21, or other leak detection methods approved by the Division of Source Testing and
Monitoring.
(i)
The owner or operator may request, in writing, an extension of the LDAR inspection interval from the Air
Program Manager of the appropriate DEP Regional Office.
(ii)
Any fugitive emissions components that are difficult to monitor or unsafe to monitor must be identified in
the monitoring plan described in Condition 3(a).
(c)
The detection devices must be operated and maintained in accordance with manufacturer-recommended
procedures, as required by the test method, or a Department-approved method.
(d)
A leak is defined as:
(i)
Any positive indication, whether audible, visual, or odorous, determined during an AVO inspection;
(ii)
Any visible emissions detected by an OGI camera;
or
(iii)
A concentration of 500 ppm or greater detected by an instrument reading.
(e)
Any leak detected using an OGI camera, a gas leak detector that meets the requirements of 40 CFR Part 60,
Appendix A-7, Method 21, or other leak detection methods approved by the Division of Source Testing and
Monitoring must be quantified using a high flow sampler or another method approved by the Department.
(f)
For quarterly inspections using a gas leak detector in accordance with 40 CFR Part 60, Appendix A-7, Method
21, the owner or operator may choose to adjust the detection instrument readings to account for the
background organic concentration level as determined according to the procedures in Section 8.3.2.
(g)
Any leak detected from a fugitive emission component shall be repaired by the owner or operator of the facility
as expeditiously as practicable. A first attempt at repair must be attempted within 5 calendar days of detection,
and repair must be completed no later than 15 calendar days after the leak is detected
unless
:
(i)
The owner or operator must purchase parts, in which case the repair must be completed no later than
10 calendar days after the receipt of the purchased parts;
or
(ii)
The repair or replacement is technically infeasible without a vent blowdown or process shutdown or
would be unsafe to repair during operation of the unit, in which case the repair or replacement must
occur at the earliest of the next scheduled or unscheduled blowdown, or within 2 years.
(h)
Once a fugitive emission component has been repaired or replaced, the owner or operator must resurvey the
component as soon as practicable, but no later than 30 calendar days after the leak is repaired.
(i)
For repairs that cannot be made during the monitoring survey when the leak is initially found, either a
digital photograph must be taken of the component or the component must be tagged for identification
purposes.
(ii)
A leak is considered repaired if:

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(A)
There are no detectable emissions consistent with Section 8.3.2 of 40 CFR Part 60, Appendix A-7,
Method 21;
(B)
A leak concentration of less than 500 ppm is detected when the gas leak detector probe inlet is
placed at the surface of the component;
(C)
There is no visible leak image when using an OGI camera;
or
(D)
There is no bubbling at the leak interface using a soap solution bubble test specified in Section
8.3.3 of 40 CFR Part 60, Appendix A-7, Method 21.
2.
Notification Requirements
The notification requirements of Section A Condition 10(b) through (d) do not apply to fugitive emissions
components.
3.
Recordkeeping Requirements
For fugitive emissions components, the owner or operator shall maintain the following records in accordance with
Section A Condition 11, including information on:
(a)
The fugitive emissions monitoring plan which must include:
(i)
The technique(s) used for determining fugitive emissions;
(ii)
A list of fugitive emissions equipment, including the manufacturer, model number, and serial number that
may be used at the facility;
(iii)
A list of personnel that may conduct the monitoring surveys at the facility, including their training and
experience;
(iv)
The procedures and timeframes for identifying and repairing fugitive emissions components from which
fugitive emissions are detected, including for those components that are unsafe-to-repair;
(v)
The procedures and timeframes for verifying fugitive emissions component repairs;
(vi)
The procedure and schedule for verifying the detection equipment is operating properly:
(A)
For OGI cameras, the following requirements are a minimum:
(1)
Must either be capable of imaging gases in the spectral range for the compound of highest
concentration in the potential fugitive emissions;
or
capable of imaging a gas that is half
methane, half propane at a concentration of 10,000 ppm at a flow rate of ≤60 g/h from a
¼ inch diameter orifice;
(2)
A procedure for a daily verification check;
(3)
A procedure for determining the operator’s maximum viewing distance from the equipment
and how the operator will ensure that this distance is maintained;
(4)
A procedure for determining maximum wind speed during which monitoring can be
performed and how the operator will ensure monitoring occurs only at wind speeds below
this threshold;
(5)
Procedures for conducting surveys including:
(i)
How the operator will ensure an adequate thermal background is present in order to
view potential fugitive emissions;
(ii)
How the operator will deal with adverse monitoring conditions, such as wind;
and
(iii)
How the operator will deal with interferences;
and
(6)
Procedures for calibration and maintenance, which must at a minimum comply with the
manufacturer’s recommendation.
(B)
For gas leak detection equipment using 40 CFR Part 60, Appendix A-7, Method 21, the following
requirements are minimum:
(1)
Verification that the monitoring equipment either meets the requirements of Section 6.0 of
Method 21 with a fugitive emissions definition of 500 ppm or greater methane using an
FID-based instrument;
or
a site-specific fugitive emissions definition that would be equivalent
for other equipment permitted in Method 21;
(2)
The instrument response factor of Section 8.1.1 must be performed using the average
composition of the fluid and not for each individual organic compound in the stream;

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(3)
For process streams that contain nitrogen, air, or other inert gases that are not organic HAPs
or VOCs, the average stream response factor must be calculated on an inert-free basis;
(4)
The detection instrument must be calibrated in accordance with Section 10.1 on each day of
its use using zero air (defined as less than 10 ppmv hydrocarbon in air) and a mixture of
methane in air at a concentration less than 10,000 ppmv as the calibration gases;
and
(5)
Procedures for conducting surveys, which at a minimum must comply with the relevant
sections of Method 21, including Section 8.3.1.
(C)
For Department-approved methods, a copy of the request for approval that shows the equivalence
to (A) or (B) above in accordance with 40 CFR §60.5397a(d).
(vii)
A sitemap;
(viii) A defined observation path that ensures that all fugitive emissions components are within sight of the
path and accounts for interferences;
(ix)
A list of all fugitive emissions components to be monitored and an identification method to locate them in
the field;
and
(x)
A written plan for all fugitive emissions components designated as difficult-to-monitor or
unsafe-to-monitor which at a minimum must include:
(A)
How a difficult-to-monitor or unsafe-to-monitor component can be identified in the field;
(B)
The reasons each component was identified as difficult-to-monitor or unsafe-to-monitor;
and
(C)
The monitoring schedule for components identified as difficult-to-monitor or unsafe-to-monitor,
which at a minimum must include one survey per year for difficult-to-monitor components.
(b)
Records of each monitoring survey which must include:
(i)
The facility name and location;
(ii)
The GP-5 authorization number;
(iii)
The date, start time, and end time of the survey;
(iv)
The name of the operator(s) performing the survey;
(v)
The monitoring instrument used;
(vi)
The ambient temperature, sky conditions, and maximum wind speed at the time of the survey;
(vii)
Any deviations from the monitoring plan or a statement that there were none;
and
(viii) Documentation of each fugitive emission including:
(A)
The identification of each component from which fugitive emissions were detected;
(B)
The instrument reading of each fugitive emissions component that meets the leak definition in
Condition 1(c)(iii) of this section;
(C)
The status of repair of each component including:
(1)
The repair methods applied in each attempt to repair the component;
(2)
The tagging or digital photographing of each component not repaired during the monitoring
survey in which the fugitive emissions were discovered;
(3)
The reasons a component was placed on delay of repair;
(4)
The date of successful repair of the component;
and
(5)
The information on the instrumentation or method used to resurvey the component after
repair, if it was not completed during the monitoring survey in which the fugitive emissions
were discovered.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the records of each monitoring survey conducted during
the reporting period shall be included.
The emissions from fugitive emissions components during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).

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SECTION L. CONTROLLERS
1. Compliance Requirements
(a)
For pneumatic controllers constructed on or after August 23, 2011, but prior to (effective date of GP-5),
constructed at:
(i)
A natural gas compressor station or transmission station, the owner or operator is required to use a
pneumatic controller with a bleed rate of less than or equal to 6 scfh, unless the owner or operator
demonstrates that a bleed rate greater than the applicable standard is required based on functional
needs including, but not limited to, response time, safety, and positive actuation.
(ii)
A natural gas processing plant, the owner or operator is required to use a pneumatic controller with a
zero bleed rate, unless the owner or operator demonstrates that a bleed rate greater than the applicable
standard is required based on functional needs including, but not limited to, response time, safety, and
positive actuation.
(b)
For controllers constructed on or after (effective date of GP-5):
(i)
If access to grid electricity is available, the owner or operator is required to install and operate an electric
controller.
(ii)
If access to grid electricity is not available, the owner or operator is required to meet the conditions of (a)
above.
(c)
Each controller must be tagged with the month and year of installation and an identification that allows
traceability with the required records.
(d)
To demonstrate compliance, the owner or operator must submit the required notifications and reports and
maintain the required records.
2.
Notification Requirements
Notifications for each controller must be done in accordance with Section A Condition 10(b) through (d). Integrated
controllers can be included in the notifications for the equipment to which they are integrated.
3.
Recordkeeping Requirements
For each controller, the owner or operator shall maintain the following records in accordance with Section A
Condition 11, including information on:
(a)
The identification, location, manufacturer’s specifications, and date of construction of each controller;
(b)
Records of the demonstration that the use of a pneumatic controller with a natural gas bleed rate greater than
the applicable standard is required;
(c)
The emissions calculation for each pneumatic controller;
and
(d)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each controller during the reporting
period shall include:
(a)
The identification, location, and date of construction for each controller constructed;
(b)
Documentation of the reasons why the use of a pneumatic controller with a natural gas bleed rate greater than
the applicable standard is required;
and
(c)
The records of deviations and malfunctions.
The emissions from each pneumatic controller during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).

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SECTION M. PUMPS
1. Compliance Requirements
(a)
For each natural gas-driven pneumatic diaphragm pump constructed on or after September 18, 2015, but prior
to (effective date of GP-5), constructed at:
(i)
A natural gas compressor station or transmission station:
(A)
The owner or operator of each pump operated less than 90 calendar days per year shall
demonstrate compliance by submitting the notification requirements of Condition 2, the reporting
requirements of Condition 4(a)(iv) and (d), and maintaining the records of Condition 3(a), (b), (i),
and (j).
(B)
At a greenfield site that operates 90 calendar days or more per year shall:
(1)
Control methane and VOC emissions from the pump by at least 95% with a condenser,
enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning device, or any
alternative method approved by the Department that meets the applicable requirements in
Section N unless the pump is the only source at the facility required to have controls;
and
(2)
Demonstrate compliance by submitting the required notifications and reports and
maintaining the required records.
(C)
At a non-greenfield site that operates 90 calendar days or more per year shall:
(1)
Control methane and VOC emissions from the pump by at least 95% with an existing
condenser, enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning device,
or any alternative method approved by the Department that meets the applicable
requirements in Section N
unless
:
(i)
It is technically infeasible to route the pneumatic diaphragm pump emissions to the
controls;
or
(ii)
The existing control device is unable to achieve a 98% reduction;
and
(2)
Demonstrate compliance by submitting the required notifications and reports and
maintaining the required records.
(ii)
A natural gas processing plant, the owner or operator of each pump shall ensure it has zero emissions of
natural gas and demonstrate compliance by submitting the required notifications and reports and
maintaining the required records.
(b)
For each pump constructed on or after (effective date of GP-5):
(i)
If access to grid electricity is available, the owner or operator is required to install and operate an electric
pump.
(ii)
If access to grid electricity is not available, the owner or operator of each natural gas-driven pneumatic
diaphragm pump shall meet the applicable requirements of (a) above except that the control requirement
for (a)(i)(B)(1) and (C)(1) is 98% for methane, VOC, and HAP.
(iii)
If access to grid electricity is not available, the owner or operator of each natural gas-driven pneumatic
pump that is not a diaphragm pump shall demonstrate compliance by submitting the notification
requirements of Condition 2, the reporting requirements of Condition 4(d), and maintaining the records of
Condition 3(a), (i), and (j).
2.
Notification Requirements
Notifications for each pump must be done in accordance with Section A Condition 10(b) through (d). Integrated
pumps can be included in the notifications for the equipment to which they are integrated.
3.
Recordkeeping Requirements
For each pump, the owner or operator shall maintain the following records in accordance with Section A Condition
11, including information on:
(a)
The identification, location, manufacturer’s specifications, and date of construction of each pump;
(b)
Records of the days of operation, if the pneumatic diaphragm pump operates less than 90 calendar days;
(c)
The control device specifications as detailed in Section N Condition 3(a) or (b),
if applicable
;

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(d)
The cover inspection required as detailed in Section N Condition 3(e),
if applicable
;
(e)
The closed vent system inspection required as detailed in Section N Condition 3(f),
if applicable
;
(f)
A statement that there is no control device present at the facility,
if applicable
;
(g)
The demonstration that the control device on site is unable to achieve the applicable reduction requirement,
if
applicable
;
or
(h)
The demonstration that it is technically infeasible to route the pneumatic diaphragm pump emissions to an
existing control,
if applicable
;
(i)
The assessment of technical feasibility to route emissions from the pneumatic pump to an existing
control device shall include, but is not limited to, safety considerations, distance from the control device,
pressure losses and pressure differentials in the closed vent system, and the ability of the control device
to handle the additional emissions;
and
(ii)
The assessment must be prepared under the direction or supervision of a qualified professional engineer
who must sign and date the assessment with the following certification: “I certify that the assessment of
technical infeasibility was prepared under my direction or supervision.
I further certify that the
assessment was conducted and this report was prepared pursuant to the requirements of
§60.5393a(b)(5)(iii). Based on my professional knowledge and experience, and inquiry of personnel
involved in the assessment, the certification submitted herein is true, accurate, and complete. I am
aware that there are penalties for knowingly submitting false information.”
(i)
The emissions calculation for each pneumatic pump;
and
(j)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each pump during the reporting
period shall include:
(a)
The identification, location, and date of construction for each pump constructed, including the certification for
pneumatic diaphragm pumps for which:
(i)
There is no control device available on site;
(ii)
It is technically infeasible to capture and route the emissions to the existing control device or process;
(iii)
The emissions from the pneumatic diaphragm pump are routed to a control or process and the level of
emissions reduction achieved;
or
(iv)
The pneumatic diaphragm pump is operated less than 90 calendar days, counting any partial day of
operation as one day;
(b)
The records of the date of installation or removal of any control device as detailed in Section N Condition 3(a)
or (b), including an update in status in accordance with (a) above;
(c)
A statement that the applicable cover, closed vent system, and/or control device requirements have been met;
and
(d)
The records of deviations and malfunctions.
The emissions from each pneumatic pump during the reporting period must be included in the emissions inventory
report of Section A Condition 12(d).
SECTION N. ENCLOSED FLARES AND OTHER EMISSION CONTROL DEVICES
1. Compliance Requirements
(a)
Enclosed Flares and Other Enclosed Combustion Control Devices.
(i)
The owner or operator of an enclosed flare or other enclosed combustion control device shall:
(A)
Ensure that the device is maintained in a leak free condition by conducting a monthly AVO
inspection;
(B)
Install and operate a continuous burning pilot flame and a heat sensing monitoring device to
ensure the presence of the pilot flame;

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(C)
Operate the device with no visible emissions except for periods not to exceed a total of 1 minute
during any 15 minute period;
(1)
A visible emissions test using Section 11 of 40 CFR Part 60, Appendix A-7, Method 22 must
be performed a least once per month using an observation period of 15 minutes.
(2)
A device that fails the visible emissions test must follow the manufacturer’s repair
instructions or best combustion engineering practice to return the unit to compliant
operations.
(3)
A visible emissions test must be performed following the maintenance or repair activity to
certify the device’s return to service.
(D)
Ensure the device is designed and operated to either:
(1)
Meet the most stringent percent reduction requirement for all sources routed to the control
device;
(2)
Reduce the concentration of TOC in the exhaust gases at the outlet of the device to a level
less than or equal to 275 ppmv as propane on a wet basis corrected to 3% O
2
as determined
in Condition 5 below;
(3)
Meet a minimum temperature of 1,600°F, provided the device has demonstrated during the
performance test that combustion zone temperature is an indicator of destruction efficiency;
or
(4)
Introduce the vent stream into the flame zone of a combustion unit or process heater that is
used as a control device.
(ii)
The owner or operator must conduct a performance test in accordance with Condition 5 within 180 days
of initial startup of the source and within 180 days of the reauthorization to use this General Permit for
each enclosed combustion device unless:
(A)
The device is a manufacturer tested model which has been operated and maintained in
accordance with the manufacturer’s instructions;
(B)
The device is a combustion unit or process heater where the vent stream is introduced with or is
used as the primary fuel;
or
(C)
The owner or operator opts to show continuing compliance by using a CPMS in accordance with
(iv) below, in which case only the initial performance test is required to establish the parameter
values.
(iii)
The owner or operator of any combustion control device that is a manufacturer tested model shall ensure
a gas flow monitoring device that meets the requirements of Condition 6(e)(i) is installed at the inlet to
the control device.
(iv)
The owner or operator of any combustion control device that opts to show continuing compliance through
a CPMS shall:
(A)
Ensure that the CPMS meets the applicable requirements of Condition 6(a);
and
either:
(B)
Install temperature monitoring devices that meet the requirements of Condition 6(c) to demonstrate
compliance with (a)(i)(D)
(3)
:
(1)
At a location representative of combustion zone temperature for a combustion control device
that establishes a correlation between combustion zone temperature and destruction
efficiency;
or
(2)
At the nearest feasible point to the inlet and outlet of a catalytic bed for a catalytic vapor
incinerator;
or
(C)
Install an organic monitoring device at the outlet of the control device to demonstrate compliance
with (a)(i)(D)
(2)
that meets the requirements of Condition 6(d).
(v)
The owner or operator shall ensure the device operates below the site specific maximum or above the
site specific minimum parameter value established in Condition 6(a)(vi) by:
(A)
Calculating the daily average of the applicable monitored parameter in accordance with Condition
6(a)(vii) except that the inlet gas flow rate to the control device shall not be averaged;
and
(B)
Ensuring that the daily average is less than or equal to the site specific maximum or greater than
or equal to the site specific minimum;
or

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(C)
Ensuring that the inlet gas flow rate does not exceed the manufacturer’s specified maximum value
at any time.
(vi)
The owner or operator of any combustion control device shall demonstrate compliance by submitting the
required notifications and reports and maintaining the required records.
(b)
Vapor Recovery Devices.
(i)
The owner or operator of a vapor recovery device shall ensure the device is designed and operated to
meet the most stringent percent reduction requirement for all sources routed to the control device by
either:
(A)
Conducting a performance test within 180 days of initial startup in accordance with Condition 5;
or
(B)
Conducting a control device design analysis including the vent stream composition, constituent
concentrations, flowrate, relative humidity, and temperature and establish:
(1)
For a condenser:
(i)
The design outlet organic compound concentration level;
(ii)
The design average temperature of the condenser exhaust vent stream;
and
(iii)
The design average temperatures of the coolant fluid at the condenser inlet and outlet;
(2)
For a regenerative carbon adsorption system:
(i)
The design exhaust vent stream organic compound concentration level;
(ii)
The adsorption cycle time;
(iii)
The number and capacity of carbon beds;
(iv)
The type and working capacity of activated carbon used for the carbon beds;
(v)
The design total regeneration stream flow over the period of each regeneration cycle;
(vi)
The design carbon bed temperature after regeneration;
(vii)
The design carbon bed regeneration time;
and
(viii) The design service life of the carbon.
(3)
For a non-regenerative carbon adsorption system:
(i)
The design exhaust vent stream organic compound concentration level;
(ii)
The capacity of the carbon bed;
(iii)
The type and working capacity of activated carbon used for the carbon beds;
(iv)
The design carbon replacement interval based on the total carbon working capacity of
the device and the source operating schedule;
and
(v)
The incorporation of dual carbon canisters in case of emission breakthrough occurring
in one canister.
(ii)
The owner or operator shall conduct a performance test in accordance with Condition 5 within 180 days
of the reauthorization to use this General Permit for each vapor recovery device unless the owner or
operator opts to show continuing compliance by using a CPMS in accordance with (iv) below, where the
parameter values are established in accordance with (i)(A) or (B) above.
(iii)
The owner or operator of any vapor recovery device shall conduct a monthly AVO inspection to ensure
the physical integrity of the control device according to the manufacturer’s instructions.
(iv)
The owner or operator that opts to show continuing compliance through a CPMS shall:
(A)
Ensure that the CPMS meets the applicable requirements of Condition 6(a);
(B)
Install temperature monitoring devices that meet the requirements of Condition 6(c) to demonstrate
compliance:
(1)
At a location in the exhaust vent stream for a condenser;
or
(2)
At each carbon bed for a regenerative carbon adsorption unit;
and
(C)
Install a gas flow monitoring device that meets the requirements of Condition 6(e)(ii) for a
regenerative carbon adsorption unit.
(v)
If the vapor recovery device is a condenser, the owner or operator shall:
(A)
Establish a site-specific condenser performance curve showing the relationship between outlet
temperature and control efficiency in accordance with Condition 6(a)(vi)(A) or (B);
(B)
Calculate the daily average condenser outlet temperature as in accordance with Condition
6(a)(vii);

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(C)
Determine the condenser efficiency for the current operating day using the daily average
condenser outlet temperature and the condenser performance curve;
(D)
Calculate the 365-day rolling average TOC emission reduction using the condenser efficiencies in
(C)
except
:
(1)
When there are less than 120 days of data, in which case the owner or operator must
calculate the average TOC emission reduction rate for the first 120 days.
(2)
When there are between 120 days and 364 days of data, in which case the owner or
operator must calculate the average TOC emission reduction rate over the number of days
between the current day and the startup date;
and
(E)
Demonstrate compliance by meeting or exceeding the applicable standard for the source being
controlled by the condenser.
(vi)
If the vapor recovery device is a regenerative carbon adsorption unit, the owner or operator shall:
(A)
Calculate the average carbon bed temperature for the duration of the steaming cycle in
accordance with Condition 6(a)(vii);
(B)
Measure the actual carbon bed temperature after regeneration and within 15 minutes of
completing the cooling cycle;
(C)
Calculate the average total regeneration stream mass flow or volumetric flow during each carbon
be regeneration cycle in accordance with Condition 6(a)(vii);
and
(D)
Replace spent carbon according to the manufacturer’s recommended replacement schedule or as
determined in (i)(B)
(2)
above.
(vii)
If the vapor recovery device is a non-regenerative carbon adsorption unit, the owner or operator shall
replace spent carbon according to the manufacturer’s recommended replacement schedule or as
determined in (i)(B)
(3)
above.
(viii) The owner or operator of any vapor recovery device shall demonstrate compliance by submitting the
required notifications and reports and maintaining the required records.
(c)
External Floating Roof.
(i)
An external floating roof shall be fitted with a primary seal and a continuous secondary seal extending
from the floating roof to the storage vessel wall with:
(A)
Seal closure devices with:
(1)
No visible holes, tears, or other openings in the seals or seal fabric;
and
(2)
Seals that are intact and uniformly in place around the circumference of the floating roof
between the floating roof and the storage vessel wall.
(B)
Automatic bleeder vents that are closed at all times except when the roof is being floated off or
landed on the roof leg supports.
(C)
Rim vents that are set to open when the roof is being floated off the leg supports or at the
recommended manufacturer’s settings.
(D)
Emergency roof drains are provided with slotted membrane fabric covers or the equivalent which
cover at least 90% of the opening.
(E)
All other openings in the external floating roof, except for leg sleeves, must be:
(1)
Equipped with covers, seals, or lids in the closed position except when in use;
and
(2)
Equipped with projections into the storage vessel which remain below the liquid surface at all
times.
(ii)
Perform a gap measurement test, as detailed in (iv) below, of the primary seal during hydrostatic testing,
within 60 days of initial fill, and at each reauthorization of this General Permit.
(A)
A mechanical shoe or liquid-mounted primary seal shall not have an accumulated area of gaps
that exceeds 10 ¼ square inches per foot of storage vessel diameter or that exceeds 1 ½ inches in
width between the primary seal and the storage vessel wall.
(B)
A vapor-mounted primary seal shall not have an accumulated area of gaps that exceeds 1 square
inch per foot of storage vessel diameter or that exceeds ⅛ inch in width between the primary seal
and the storage vessel wall.

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(iii)
Perform a gap measurement test, as detailed in (iv) below, of the secondary seal within 60 days of initial
fill and annually thereafter.
(A)
A mechanical shoe or liquid-mounted primary seal’s secondary seal shall not have an accumulated
area of gaps that exceeds 1 square inch per foot of storage vessel diameter or that exceeds ½
inch in width between the secondary seal and the storage vessel wall.
(B)
A vapor-mounted primary seal’s secondary seal shall not have an accumulated area of gaps that
exceeds 1 square inch per foot of storage vessel diameter or that exceeds ⅛ inch in width
between the secondary seal and the storage vessel wall.
(iv)
To perform the gap measurement test, the inspector shall hold a ⅛ inch diameter probe against the
storage vessel wall and attempt to slide the probe between the seal and the wall.
(A)
The probe must move between the seal and the wall without forcing or binding against the seal in
order to constitute a gap.
(B)
The length of the gap shall be determined by sliding the probe along the vessel wall in each
direction as far as it will travel freely.
(C)
The maximum gap width shall be determined by inserting probes of various diameters (in ⅛ inch
increments) between the seal and the vessel wall, with the largest diameter that moves freely
between the seal and the wall being the maximum diameter.
(D)
Determine the area of a gap by multiplying the average width, determined as the simple average of
the ⅛ inch probe and the diameter of the largest probe, by the gap length.
(E)
Sum all gap areas and divide by the vessel’s nominal diameter to determine the accumulated area
of gaps.
(v)
Visually inspect the external floating roof, primary seal, and secondary seal at least annually to
determine if the roof has defects or if the primary or secondary has holes or tears in the seal fabric.
(vi)
Any defect detected during a visual inspection or gap measurement test must be repaired within 45 days,
unless a request for extension is sent to the Air Program Manager of the appropriate DEP Regional
Office.
(vii)
The owner or operator of an external floating roof shall demonstrate compliance by submitting the
required notifications and reports and maintaining the required records.
(d)
Internal Floating Roof.
(i)
An internal floating roof shall be fitted with a primary seal with:
(A)
A closure seal or seals to close the space between the roof edge and tank wall.
(B)
No holes, tears, or other openings in the seal, seal fabric, or seal materials.
(C)
All openings, except for stub drains, are equipped with covers, lids, or seals such that:
(1)
The cover, lid, or seal is closed at all times except when in use;
(2)
Automatic bleeder vents are closed at all times except when the roof is floated off or landed
on the roof leg supports;
and
(3)
Rim vents are set to open when the roof is being floated off the roof leg supports or at the
recommended manufacturer’s settings.
(D)
If the internal floating roof is a non-contact roof, each opening except for automatic bleeder vents
and rim vents are to provide a projection below the liquid surface.
(ii)
Visually inspect the internal floating roof, primary seal, and secondary seal (if equipped) prior to the initial
fill and at each reauthorization of this General Permit for holes, tears, or other openings in the seal, seal
fabric, or seal materials.
(iii)
Visually inspect the internal floating roof, primary seal, and secondary seal (if equipped) through
manholes and roof hatches on the fixed roof at least annually to determine if the roof is resting on the
surface of the liquid, if there is liquid accumulated on the roof, if the seal is detached, or if there are holes
or tears in the seal fabric.
(iv)
Any defect detected during a visual inspection must be repaired within 45 days, unless a request for
extension is sent to the Air Program Manager of the appropriate DEP Regional Office.
(v)
The owner or operator of an internal floating roof shall demonstrate compliance by submitting the
required notifications and reports and maintaining the required records.

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(e)
Covers.
(i)
The cover and all openings on the cover shall form a continuous impermeable barrier over the entire
surface area of the liquid.
(ii)
Each cover opening shall be secured in a closed, sealed position whenever material is in the unit except
during those times it is necessary to use an opening as follows:
(A)
Adding or removing material from the unit, including openings necessary to equalize or balance
the internal pressure of the unit following changes in the level of the material in the unit;
(B)
Inspecting or sampling the material in the unit;
(C)
Inspecting, maintaining, repairing, or replacing equipment located inside the unit;
or
(D)
Venting liquids, gases, or fumes from the unit through a closed vent system designed and
operated in accordance with (f) below.
(iii)
Each storage vessel thief hatch shall be equipped, maintained, and operated with a weighted
mechanism or the equivalent to ensure that the lid remains properly seated and sealed under normal
operating conditions including when working, breathing, and flash emissions may be generated. The
owner or operator must select gasket material for the hatch based on composition of the fluid in the
storage vessel and weather conditions.
(iv)
The owner or operator shall conduct AVO inspections for defects that could result in air emissions in
accordance with Section K Condition 1(a). Defects include, but are not limited to, visible cracks, holes,
or gaps in the cover or between the cover and the separator wall; broken, cracked, or otherwise
damaged seals or gaskets on closure devices; and broken or missing hatches, access covers, caps, or
other closure devices.
(v)
Any defect or leak detected shall be repaired in accordance with Section K Condition 1(f).
(vi)
The owner or operator of a cover shall demonstrate compliance by submitting the required notifications
and reports and maintaining the required records.
(f)
Closed Vent Systems.
(i)
The owner or operator shall conduct an assessment that the closed vent system is of sufficient design
and capacity to route all gases, vapors, and fumes emitted from the material in the unit to a control
device or process of sufficient design and capacity to accommodate all emissions from the source. The
owner or operator must have the design certified by a qualified engineer by performing the assessment
under the direction or supervision of the qualified professional engineer that signs the following
certification:
“I certify that the closed vent system design and capacity assessment was prepared under my
direction and supervision.
I further certify that the closed vent system design and capacity
assessment was conducted and this report was prepared pursuant to the requirements of 40 CFR
Part 60, Subpart OOOOa. Based on my professional knowledge and experience, the certification
submitted herein is true, accurate, and complete.
I am aware that there are penalties for
knowingly submitting false information.”
(ii)
The owner or operator shall design and operate the closed vent system with no detectable emissions, as
determined in accordance with Section K Condition 1(a) and (b).
(iii)
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 or process,
unless
the bypass
device is on a low leg drain, high point bleed, analyzer vent, open-ended valve or line, or safety device,
the owner or operator shall:
(A)
Install, calibrate, maintain, and operate a flow indicator at the inlet to the bypass device that
sounds an alarm or initiates notice via a remote alarm to the nearest field office when the bypass
device is open such that the stream is, or could be, diverted away from the control device or
process;
or
(B)
Secure the valve installed at the inlet to the bypass device in the non-diverting position using a car-
seal or a lock-and-key type configuration.

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(iv)
The owner or operator shall conduct AVO inspections for defects that could result in air emissions in
accordance with Section K Condition 1(a). Defects include, but are not limited to, visible cracks, holes,
or gaps in ductwork; loose connections; liquid leaks; and broken or missing caps or other closure
devices.
(v)
The owner or operator shall either:
(A)
Set the flow indicator at the inlet to a bypass device to take a reading once every 15 minutes;
or
(B)
Visually inspect that a bypass device secured by a car-seal or lock-and-key at least once a month
to ensure the bypass device is in the non-diverting position and the vent stream is not being
diverted through the bypass device.
(vi)
Any defect or leak detected shall be repaired in accordance with Section K Condition 1(f).
(vii)
The owner or operator of a closed vent system shall demonstrate compliance by submitting the required
notifications and reports and maintaining the required records.
2.
Notification Requirements
Notifications for each control device must be done in accordance with Section A Condition 10(b) through (d).
Notifications for performance testing of each control device must be done in accordance with Section A Condition
13(f) and (g).
3.
Recordkeeping Requirements
For each control device, the owner or operator shall maintain the following records in accordance with Section A
Condition 11, including information on:
(a)
Enclosed Flares and Other Enclosed Combustion Control Devices.
(i)
For non-manufacturer tested models:
(A)
The results of all inspections;
(B)
The heat sensing monitoring device data;
(C)
Records of the visible emissions tests;
(D)
The manufacturer’s written operating instructions, procedures, and maintenance schedule;
(E)
Records of the maintenance and repair activities;
(F)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
(G)
The site-specific monitoring plan,
if applicable
;
and
(H)
The temperature monitoring device data,
if applicable
.
(ii)
For manufacturer tested models:
(A)
In addition to (i)(A) through (H) above, the records of the manufacturer’s performance test
information including:
(1)
The make, model, and serial number of the device;
(2)
The date of purchase and a copy of the purchase order;
(3)
A full schematic of the control device and dimensions of the device components;
(4)
The maximum net heating value of the device;
(5)
The test fuel gas flow range in mass and volume, including the maximum allowable inlet gas
flow rate;
(6)
The air/steam injection/assist ranges, if used;
(7)
The test conditions as applicable for the tested model:
(i)
Fuel gas delivery pressure and temperature;
(ii)
Fuel gas moisture range;
(iii)
Purge gas usage range;
(iv)
Condensate separation range;
(v)
Combustion zone temperature range;
(vi)
Excess air range;
(vii)
Flame arrestor(s);
(viii) Burner manifold;

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(ix)
Pilot flame indicator;
(x)
Pilot flame design fuel and calculated or measured fuel usage;
(xi)
Tip velocity range;
(xii) Momentum flux ratio;
(xiii) Exit temperature range;
(xiv) Exit flow rate; and
(xv) Wind velocity and direction.
(8)
Calibration QA/QC data, calibration gas values, gas cylinder certification, strip charts, or
other graphic presentations of the data annotated with test times and calibration values;
and
(B)
The gas flow monitoring device data.
(b)
Vapor Recovery Devices.
(i)
For a Condenser:
(A)
The manufacturer’s written operating instructions, procedures, and maintenance schedule;
(B)
Records of the maintenance and repair activities;
(C)
The design analysis,
if applicable
;
(D)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
(E)
The site-specific condenser performance curve;
(F)
The site-specific monitoring plan;
(G)
The temperature monitoring device data;
(H)
The results of all compliance calculations;
and
(I)
The results of all inspections.
(ii)
For a Carbon Adsorption Unit:
(A)
The manufacturer’s written operating instructions, procedures, and maintenance schedule;
(B)
Records of the maintenance and repair activities;
(C)
The design analysis,
if applicable
;
(D)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
(E)
The site-specific monitoring plan,
if applicable
;
(F)
The temperature monitoring devices data,
if applicable
;
(G)
The gas flow monitoring device data,
if applicable
;
(H)
The results of all inspections;
(I)
The carbon replacement schedule;
and
(J)
Records of each carbon replacement including the disposition of the spent carbon.
(c)
External Floating Roof.
(i)
The determination of the maximum true vapor pressure as determined under actual storage conditions
using a temperature representative of the average storage temperature for the hottest month of the year;
(ii)
Records of each time the roof is floated off or landed on the roof leg supports;
(iii)
The results of each visual inspection of the roof, primary seal, and secondary seal;
(iv)
The results of each gap measurement test of the primary seal and secondary seal;
and
(v)
Records of the maintenance and repair activities.
(d)
Internal Floating Roof.
(i)
The determination of the maximum true vapor pressure as determined under actual storage conditions
using a temperature representative of the average storage temperature for the hottest month of the year;
(ii)
Records of each time the roof is floated off or landed on the roof leg supports;
(iii)
The results of each visual inspection of the roof, primary seal, and secondary seal (if equipped);
and
(iv)
Records of the maintenance and repair activities.
(e)
Covers.
(i)
The results of each visual inspection of the cover;
and
(ii)
Records of the maintenance and repair activities.
(f)
Closed Vent Systems.

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(i)
Records of the assessment including the engineer’s certification;
(ii)
The results of each visual inspection of the closed vent system and each bypass device;
(iii)
Either records of each time the alarm is triggered for each bypass device;
or
records of each time the
key is signed out for a secured bypass device;
(iv)
The results of each monitoring survey to meet the no detectable emissions requirements;
and
(v)
Records of the maintenance and repair activities.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each control device during the
reporting period shall include:
(a)
Enclosed Flares and Other Enclosed Combustion Control Devices.
(i)
For non-manufacturer tested models:
(A)
The records of the results of all inspections conducted;
(B)
The records of the heat sensing monitoring device data;
(C)
The records of the visible emissions tests conducted;
(D)
The records of the maintenance and repair activities conducted;
(E)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
and
(F)
The records of the temperature monitoring device data,
if applicable
.
(ii)
For manufacturer tested models:
(A)
In addition to (i)(A) through (F) above, the records of the manufacturer’s performance test
information of Condition 3(a)(ii)(A) above, unless the test results for that model of combustion
control device are posted at
www.epa.gov/airquality/oilandgas/
;
and
(B)
The records of the gas flow monitoring device data.
(b)
Vapor Recovery Devices.
(i)
For a Condenser:
(A)
The records of the maintenance and repair activities conducted;
(B)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
(C)
The records of the temperature monitoring device data;
(D)
The records of the results of all compliance calculations;
and
(E)
The records of the results of all inspections conducted.
(ii)
For a Carbon Adsorption Unit:
(A)
The records of the maintenance and repair activities conducted;
(B)
The summary for each complete test report described in Section A Condition 13(h) conducted,
if
applicable
;
(C)
The records of the results of all inspections conducted;
(D)
The records of the temperature monitoring device data,
if applicable
;
(E)
The records of the gas flow monitoring device data,
if applicable
;
(F)
The records of the carbon replacement schedule;
and
(G)
The records of each carbon replacement including the disposition of the spent carbon.
(c)
External Floating Roof.
(i)
The records of each time the roof is floated off or landed on the roof leg supports;
(ii)
The records of each visual inspection of the roof, primary seal, and secondary seal;
(iii)
The records of each gap measurement test of the primary seal and secondary seal;
and
(iv)
The records of the maintenance and repair activities conducted.
(d)
Internal Floating Roof.
(i)
The records of each time the roof is floated off or landed on the roof leg supports;
(ii)
The records of each visual inspection of the roof, primary seal, and secondary seal (if equipped);
and
(iii)
The records of the maintenance and repair activities conducted.
(e)
Covers.

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(i)
The records of each visual inspection of the cover conducted;
and
(ii)
The records of the maintenance and repair activities conducted.
(f)
Closed Vent Systems.
(i)
The records of each visual inspection of the closed vent system and each bypass device conducted;
(ii)
Either the records of each time the alarm is triggered for each bypass device;
or
the records of each time
the key is signed out for a secured bypass device;
(iii)
The records of each monitoring to meet the no detectable emissions requirements;
and
(iv)
The records of the maintenance and repair activities conducted.
5.
Performance Testing Requirements
The performance test for each control device using the following procedure may forgo the submission of the test
protocol in Section A Condition 13(e). Any other method for determining compliance must submit the test protocol
described in Section A Condition 13(e) for review and approval.
(a)
Conduct three test runs of at least one hour duration.
(b)
Select the sampling port location and the number and location of traverse points at the exhaust using 40 CFR
Part 60, Appendix A-1, Method 1 or 1A depending on stack diameter.
(i)
If demonstrating compliance with a percent reduction requirement, sampling sites must be located at the
inlet of the first control device and the outlet of the final control device;
or
(ii)
If demonstrating compliance with an outlet concentration requirement, the sampling site must be located
at the outlet of the control device.
(c)
Determine the effluent characteristics including:
(i)
The flow velocity, stack temperature, static pressure, and barometric pressure using 40 CFR Part 60,
Appendix A-1, Method 2 or 2C depending on stack diameter;
(ii)
The gas density using 40 CFR Part 60, Appendix A-2, Method 3A;
and
(iii)
The moisture content using 40 CFR Part 60, Appendix A-3, Method 4.
(d)
To demonstrate compliance with (b)(i) use 40 CFR Part 60, Appendix A-7, Method 25A to determine the TOC
and then convert to dry basis using the moisture content from (c)(iii) above and calculate the inlet and outlet
mass rates as propane and the percent reduction.
(e)
To demonstrate compliance with (b)(ii) use 40 CFR Part 60, Appendix A-7, Method 25A to determine the TOC
and 40 CFR Part 60, Appendix A-6, Method 18 to determine the methane and ethane concentration and then
correct the TOC concentration, minus methane and ethane, for percent oxygen from (c)(ii) above.
6.
Periodic Monitoring Requirements
(a)
If required to install a continuous parameter monitoring system, the owner or operator shall:
(i)
Ensure that the CPMS measures and records data values at least once every hour and records each
block average value calculated from all measured data values during each period.
(ii)
Prepare a site-specific monitoring plan that addresses the monitoring system design, data collection, and
the quality assurance and quality control elements below:
(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 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 the provisions in 40 CFR
§60.13(b);
and
(E)
Ongoing reporting and recordkeeping procedures in accordance with provisions in 40 CFR
§60.7(c),(d), and (f).
(iii)
Install, calibrate, operate, and maintain each CPMS according to the procedures in the approved site-
specific monitoring plan.
(iv)
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.

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(v)
Conduct a performance evaluation of each CPMS in accordance with the site-specific monitoring plan.
(vi)
Establish a minimum or maximum operating parameter value for each CPMS, as appropriate to the
control device, to define the conditions at which the control device must be operated to continuously
achieve the applicable performance requirements.
(A)
If the owner or operator conducts a performance test to demonstrate that the control device
achieves the applicable performance standards, then the minimum or maximum operating
parameter should be established based on values measured during the performance test and
supplemented, if necessary, by the design analysis or control device manufacturer’s
recommendations.
(B)
If the owner or operator uses a design analysis to demonstrate that the control device achieves the
applicable performance standards, then the minimum or maximum operating parameter should be
established based on the design analysis and supplemented, if necessary, by the manufacturer’s
recommendations.
(C)
If the owner or operator operates a control device where the performance testing was done by the
equipment manufacturer, then the control device inlet gas flow rate must not exceed the maximum
inlet gas flow rate determined by the manufacturer.
(vii)
Calculate the daily average value for each monitored operating parameter for each operating day, using
the data recorded by the CPMS. If the emissions unit operation is continuous, the operating day is a
24-hour period. If the emissions unit operation is not continuous, the operating day is the total number of
hours of control device operation per 24-hour period. Valid data points must be available for 75% of the
operating hours in an operating day to compute the daily average.
(viii) Ensure that the CPMS is operating at all times the affected source is operating except during periods of
CPMS malfunction, repairs related to CPMS malfunctions, and required CPMS QA/QC activities
including, but not limited to, system accuracy audits, zero adjustments, and span adjustments.
(ix)
Not use data recorded during CPMS malfunctions, repairs of CPMS malfunctions, or required CPMS
QA/QC activities in calculations used to report emissions or operating levels.
(x)
Report any failure to collect required data as a deviation except during periods of CPMS malfunctions,
repairs related to CPMS malfunctions, or required CPMS QA/QC activities.
(b)
Heat sensing monitoring devices to detect the presence of a pilot flame are exempt from the calibration and
QA/QC requirements of the site-specific monitoring plan.
(c)
Temperature monitoring devices shall be accurate to ±1% of the temperature being monitored or ±4.5°F,
whichever is greater.
(d)
The owner or operator of any control device that must, or that chooses to, monitor the outlet organic
concentration shall:
(i)
Ensure that the organic monitoring device meets the requirements of Performance Specification 8 or 9 of
40 CFR Part 60 Appendix B;
and
(ii)
Must install, calibrate, and maintain the monitor according to the manufacturer’s specifications.
(e)
The owner or operator of any control device that must monitor the gas flow rate shall:
(i)
For a combustion control device whose model is tested by the manufacturer, ensure that the gas flow
meter is accurate to ±2% or better of the maximum flow rate.
(ii)
For a regenerative carbon adsorption unit:
(A)
Ensure that the gas flow meter is accurate to ±5% of the flow rate or 10 cfm, whichever is greater;
and
(B)
Inspect the gas flow CPMS monthly for leakage in the mechanical connections and quarterly for
physical and operational integrity of all components and oxidation and galvanic corrosion of all
electrical connections unless equipped with a redundant flow sensor.
SECTION O. PIGGING OPERATIONS
1. Compliance Requirements
(a)
The owner or operator that conducts pigging operations shall:
(i)
Install a liquids drain into each pig receiver chamber;
and

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(ii)
Route each high pressure pig launcher and receiver chamber to a low pressure line or vessel,
if
available
.
(b)
The owner or operator that conducts pigging operations shall use additional best management practices
including, but not limited to, using ball valve type chambers or multiple pig chambers.
(c)
For pigging operations with an uncontrolled methane emission rate of 200 tpy or greater, a total uncontrolled
VOC emission rate of 2.7 tpy or greater, an uncontrolled single HAP emission rate of 0.5 tpy or greater, or a
total uncontrolled HAP emission rate of 1.0 tpy or greater, the owner or operator shall:
(i)
Control methane, VOC and HAP emissions from all pigging operations by at least 98% with a condenser,
enclosed flare, thermal oxidizer, vapor recovery unit, or other air cleaning device, or any alternative
method approved by the Department that meets the applicable requirements in Section N;
and
(ii)
Demonstrate compliance by submitting the required notifications and reports and maintaining the
required records.
(d)
For pigging operations with an uncontrolled methane emission rate of less than 200 tpy, a total uncontrolled
VOC emission rate of less than 2.7 tpy, an uncontrolled single HAP emission rate of less than 0.5 tpy, and a
total uncontrolled HAP emission rate of less than 1.0 tpy, the owner or operator shall demonstrate compliance
by submitting the required notifications and reports and maintaining the required records.
2.
Notification Requirements
Notifications for the construction of pig launchers and receivers must be done in accordance with Section A Condition
10(b) through (d). Notifications for pigging operations that vent to the atmosphere must be done in accordance with
Section A Condition 10(e).
3.
Recordkeeping Requirements
For each pigging operation, the owner or operator shall maintain the following records in accordance with Section A
Condition 11, including information on:
(a)
The identification, location, and date of construction of each pig launcher or receiver;
(b)
Records of each pigging operation including the identification of the pig chamber used, the date and time of the
pigging operation, and the type and volume of liquids cleared;
(c)
Records of the control device specifications as detailed in Section N Condition 3(a) and (b),
if applicable
;
(d)
Records of the cover inspection required as detailed in Section N Condition 3(e),
if applicable
;
(e)
Records of the closed vent system inspection required as detailed in Section N Condition 3(f),
if applicable
;
(f)
The emissions calculation for each pig chamber, using the Department’s spreadsheet found at
http://files.dep.state.pa.us/
or other equivalent method;
and
(g)
Records of deviations and malfunctions.
4.
Reporting Requirements
In the required annual report of Section A Condition 12(c), the information about each pigging operation conducted
during the reporting period shall include:
(a)
The records of the emissions from each pig chamber;
(b)
A statement that the applicable cover, closed vent system, and/or control device requirements have been met;
and
(c)
The records of deviations and malfunctions.
The emissions from each pigging operation conducted during the reporting period must be included in the emissions
inventory report of Section A Condition 12(d).
Issued by:
Krishnan Ramamurthy

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Acting Director,
Bureau of Air Quality
Date Issued:

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