Southern Ute Indian Tribe (2024)

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Southern Ute Indian Tribe

Air Quality Division

Title V Operating Permit

Southern Ute Indian Tribe

Environmental Programs Department

Air Quality Division

71 Mike Frost Way

Ignacio, Colorado 81137

AIR POLLUTION CONTROL

TITLE V PERMIT TO OPERATE

In accordance with the provisions of Title V of the Clean Air Act (42 U.S.C. 7661-7661f) and Part

1, Article II of the Southern Ute Indian Tribe/State of Colorado Environmental Commission’s

Reservation Air Code (RAC) and applicable rules and regulations,

Red Cedar Gathering Company

Trail Canyon Compressor Station

is authorized to operate air emission units and to conduct other air pollutant emitting activities in

accordance with the conditions listed in this permit.

This source is authorized to operate at the following location:

Southern Ute Indian Reservation

Section 1, T32N, R9W

La Plata County, Colorado

Terms not otherwise defined in this permit have the meaning assigned to them in the referenced

regulations. All terms and conditions of the permit are enforceable by the Tribe and citizens under

the Clean Air Act.

Daniel Powers, Air Quality Division Head

Environmental Programs Department

Southern Ute Indian Tribe

AIR POLLUTION CONTROL

TITLE V PERMIT TO OPERATE

Red Cedar Gathering Company

Trail Canyon Compressor Station

SUIT Account Identification Code: 2-027

Permit Number: V-SUIT-0048-2024.01

[Replaces Permit No.: V-SUIT-0048-2024.00]

Initial Issue Date:

Revised Date:

Expiration Date:

July 21, 2025

September 9, 2025

July 21, 2030

The SUIT account identification code and permit number cited above should be referenced in future

correspondence regarding this facility.

Permit Issuance History

DATE

TYPE OF

ACTION

DESCRIPTION OF ACTION

PERMIT

NUMBER

September 2009

Permit Issued

Initial Part 71 Permit Issued

# V-SU-0048-08.00

October 2009

Permit Revision

Administrative Amendment

# V-SU-0048-08.01

February 2011

Reopen for Cause

May 2012

Permit Revision

Minor Modification

# V-SU-0048-2008.03

January 2014

Permit Issued

Initial Part 70 Permit Issued

Replaces EPA-Issued Permit:

V-SU-0048-2008.03

# V-SUIT-0048-2014.00

September 2014

Permit Revision

Administrative Amendment

# V-SUIT-0048-2014.01

August 12, 2019

# V-SU-0048-2008.02

Permit Renewal

1 Part 70 Permit Renewal

# V-SUIT-0048-2019.00

February 13, 2023

Permit Revision

Minor Permit Revision

Added compressor engine C206 updated affected units for

40 CFR 60, Subpart OOOOa.

 Updated C-205 engine serial

number and installation date.

 Updated Quad Z performance

testing language.

# V-SUIT-0048-2019.01

July 21, 2025

Permit Renewal

2nd Part 70 Permit Renewal

# V-SUIT-0048-2024.00

Administrative Revision

Added language to 40 CFR 60,

Subpart OOOOb, due to the 2025

EPA Final Interim Rule

extending compliance deadlines

for 40 CFR 60, Subpart

OOOO/a/b/c.

# V-SUIT-0048-2024.01



September 9, 2025

Permit Revision

Table of Contents

Abbreviations and Acronyms ................................................................................................................................. 3

Section I – Source Information and Emission Unit Identification ............................................................................ 6

Source Information ..........................................................................................................................................6

Source Emission Points ....................................................................................................................................7

Section II – General Requirements ......................................................................................................................... 8

Title V Administrative Requirements ...............................................................................................................8

1.1.

Annual Fee Payment [RAC 2-110(1)(h) and RAC 2-118] ........................................................................ 8

1.2.

Compliance Requirements .................................................................................................................. 10

1.3.

Duty to Provide and Supplement Information [RAC 2-110(7)(e), 2-106(5), and 2-124] ....................11

1.4.

Submissions [RAC 2-105] .....................................................................................................................12

1.5.

Severability Clause [RAC 1-106 and RAC 2-110(1)(f)] .........................................................................12

1.6.

Permit Actions [RAC 2-110(3)] ............................................................................................................ 12

1.7.

Administrative Permit Revision [RAC 2-111(2)] .................................................................................13

1.8.

Minor Permit Revisions [RAC 2-111(3)] ..............................................................................................13

1.9.

Significant Permit Revisions [RAC 2-111(4)] .......................................................................................14

1.10.

Permit Reopenings, Revocations and Reissuances, and Terminations [RAC 2-112] .........................14

1.11.

Property Rights [RAC 2-110(3)(e)] .......................................................................................................16

1.12.

Inspection and Entry [RAC 2-110(9)(b)] ..............................................................................................16

1.13.

[Reserved] ............................................................................................................................................16

1.14.

Permit Transfers [RAC 2-113] ..............................................................................................................16

1.15.

Off-Permit Changes [RAC 2-116(2)]..................................................................................................... 16

1.16.

Permit Expiration and Renewal ..........................................................................................................17

Facility-Wide Requirements...........................................................................................................................18

2.1.

General Recordkeeping Requirements [RAC 2-110(6)] ...................................................................... 18

2.2.

General Reporting Requirements .......................................................................................................19

2.3.

Alternative Operating Scenarios [RAC 2-110(8)] ................................................................................20

2.4.

Permit Shield [RAC 2-110(10)(c)].........................................................................................................22

2.5.

Stratospheric Ozone and Climate Protection [40 CFR Part 82] ..........................................................22

Section III – Site Specific Permit Terms ................................................................................................................ 23

New Source Performance Standards (NSPS) and 40 CFR Part 60 ..................................................................23

1.1.

40 CFR Part 60, Subpart OOOOb – Standards of Performance for Crude Oil and Natural Gas

Facilities for Which Construction, Modification or Reconstruction Commenced After December 6, 2022 [40

CFR 60.5360b - 60.5439b] ..................................................................................................................................23

National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR Part 63 ...........................51

2.1.

40 CFR Part 63, Subpart HH – National Emission Standards for Hazardous Air Pollutants From Oil

and Natural Gas Production Facilities [40 CFR 63.760 – 63.779, RAC 4-103] ...................................................51

2.2.

40 CFR Part 63, Subpart ZZZZ – National Emission Standards for Hazardous Air Pollutants from Oil

and Natural Gas Production Facilities [40 CFR §63.6580 – 63.6675 and RAC §4-103] .....................................62

Reserved – Tribal Minor New Source Review ................................................................................................86

3.1

Federal Implementation Plan for Managing Air Emissions from True Minor Sources in Indian

Country in the Oil and Natural Gas Production and Natural Gas Processing Segments of the Oil and Natural

Gas Sector [40 CFR 49.101-49.105] [SU-000048]...............................................................................................86

Reserved – Prevention of Significant Deterioration Requirements ............................................................... 86

Reserved – Consent Decree Requirements ....................................................................................................86

Reserved – Compliance Assurance Monitoring (CAM) Requirements ...........................................................86

Enhanced Monitoring, Recordkeeping, and Reporting..................................................................................86

Section IV – Appendix .......................................................................................................................................... 88

Inspection Information ..................................................................................................................................88

1.1.

Driving Directions: ...............................................................................................................................88

1.2.

Global Positioning System (GPS): .......................................................................................................88

1.3.

Safety Considerations: ........................................................................................................................88

Abbreviations and Acronyms

4SLB

4SRB

AFS

AQD

bbl

BACT

CAA

CAM

CEMS

CFR

CMS

COMS

CO2

dscf

dscm

EPA

gal

GPM

H 2S

HAP

lbs

MACT

MMBtu

MMSCFD

NESHAP

NMHC

NOx

NSPS

NSR

PM10

ppbvd

ppm

ppmvd

PSD

PTE

psi

psia

RAC

RICE

RMP

scf

scfm

SO2

SUIT

tpy

Tribe

Four-Stroke Lean-Burn

Four-Stroke Rich-Burn

Air Facility System database

Southern Ute Indian Tribe’s Air Quality Division

Barrels

Best Available Control Technology

Clean Air Act [42 U.S.C. Section 7401 et seq.]

Compliance Assurance Monitoring

Continuous Emission Monitoring System

Code of Federal Regulations

Continuous Monitoring System (includes COMS, CEMS and diluent monitoring)

Continuous Opacity Monitoring System

Carbon monoxide

Carbon dioxide

Dry standard cubic foot

Dry standard cubic meter

United States Environmental Protection Agency

Gallon

Gallons per minute

Hydrogen sulfide

Hazardous Air Pollutant

Hour

Identification Number

Kilogram

Pounds

Maximum Achievable Control Technology

Megagram

Million British Thermal Units

Million standard cubic feet per day

Month

National Emission Standards for Hazardous Air Pollutants

Non-methane hydrocarbons

Nitrogen Oxides

New Source Performance Standard

New Source Review

Negative logarithm of effective hydrogen ion concentration (acidity)

Particulate Matter

Particulate matter less than 10 microns in diameter

Parts per billion by volume, dry

Parts per million

Parts per million by volume, dry

Prevention of Significant Deterioration

Potential to Emit

Pounds per square inch

Pounds per square inch absolute

Southern Ute Indian Tribe/State of Colorado Environmental Commission’s Reservation

Air Code

Reciprocating Internal Combustion Engine

Risk Management Plan

Standard cubic feet

Standard cubic feet per minute

Spark Ignition

Sulfur Dioxide

Southern Ute Indian Tribe

Ton(s) Per Year

Southern Ute Indian Tribe

US EPA

VOC

United States Environmental Protection Agency

Volatile Organic Compounds

Table of Figures

Table 1 - Emission Units................................................................................................................. 7

Table 2 - Insignificant Emission Units ........................................................................................... 7

Section I – Source Information and Emission Unit Identification

Source Information

Owner Name:

Red Cedar Gathering Company

Facility Name:

Trail Canyon Compressor Station

Facility Location:

Section 1, T32N, R9W

Latitude:

37.049720 °N

Longitude:

State:

-107.781940 °W

Colorado

County:

La Plata

Responsible Official:

President – Chief Operating Officer

SIC Code:

1311

ICIS Identification Number:

SU00000008067U0021

EPA Facility Registry ID:

110063859267

Other Clean Air Act Permits

Federal Implementation Plan: # SU-000048

Process Description:

The Trail Canyon Compressor Station, owned and operated by Red Cedar Gathering Company, is

located in Southwestern Colorado within the exterior boundaries of the Southern Ute Indian

Reservation. Trail Canyon is a production field facility prior to the point of custody transfer.

Natural gas product is provided to Trail Canyon from several upstream wells and compression

stations.

Current Configuration: Units C-204 and C-205 pull gas from the low-pressure pipelines at

approximately 30psi and compress the gas to approximately 350psi. The gas is then processed

through the dehy unit and discharged into Red Cedar’s mid-pressure pipeline. Under this

configuration, the station can process 10-12 Mscf/day. Units C-201, C-202, and C-206 boost 5060 MMscf/day of high-pressure gas, from various compressor facilities, from roughly 800psi to a

discharge pressure around 1,000psi. The gas is discharged to a high-pressure valve set known as

the Val Verde Valve set. The gas that is processed through units C-201 and C-202 is not dehydrated

at the Trail Canyon Compressor Station. The facility does not extract natural gas liquids from field

gas nor fractionate mixed NGL’s to natural gas products. The facility has storage vessels, but none

with the potential for flash emissions. Trail Canyon’s primary emitters consist of 5 compressor

engines and one glycol dehydration unit. The facility has several heaters, and tanks that qualify as

insignificant emission units. Trail Canyon does not engage in pigging operations.

The 5 compressor engines are 4SLB SI RICE. One of these compressor engines (C-204) is subject

to 40 CFR 63 Subpart ZZZZ regulations. Red Cedar has selected oxidation catalyst as the means

to satisfy the regulatory requirements for Carbon Monoxide (CO) reduction.

Source Emission Points

Table 1 - Emission Units

Emission

Unit ID

Control

Equipment

Description

Caterpillar G3516LE (4SLB SI) Natural Gas-Fired Compressor Engine

1,150 Name Plate Rated HP

C-201

Serial No.

4EK01712

Install Date:

06/10/2025

C-202

Serial No.

4EK02752

Install Date:

07/07/2009

C-206

Serial No.

4EK02291

Install Date:

11/19/2024

None

Caterpillar G3516LE (4SLB SI) Natural Gas-Fired Compressor Engine

1,342 Name Plate Rated HP

C-204

Serial No.

4EK04171

Install Date:

Miratech Oxidation

Catalyst with AFRC

03/24/2025

Waukesha 7042GL (4SLB SI) Natural Gas-Fired Compressor Engine

1,377 Name Plate Rated HP

C-205

Serial No.

C-12572/4

Install Date:

None

12/21/2022

PESCO Tri-Ethylene Glycol (TEG) Dehydrator 25 (MMscf/day)

None

X-303

Serial No.

N/A

Install Date:

05/06/2009

Table 2 - Insignificant Emission Units

Emission Unit ID

Amount

Description

Size

Units

X-303a

H-101, 102

H-501, 502

H-603, 701, 702

TK-501

TK-502

TK-503

TK-505, 512, 513, 521

TK-506

TK-508, 509

TK-514

TK-515, 516

TK-517, 518

TK-601

TK-602

FUG

N/A

TEG Reboiler

Catalytic Heater

Tank Heater

Catalytic Heater

Waste Water Drain Tank

Waste Oil Drain Tank

Glycol Still Vent Tank

Engine Coolant Makeup Tank

Engine Lube Oil Makeup Tank

Compressor Lube Oil Makeup Tank

Compressor Lube Oil Tank

Compressor Oil Day Tank

Engine Oil Day Tank

Glycol Makeup (Storage) Tank

TEG Stock Tank

Fugitive Emissions

0.65

0.10

0.325

0.005

15,750

6,615

788

500

375

N/A

MMBtu/hr

Gallons

Section II – General Requirements

Title V Administrative Requirements

1.1. Annual Fee Payment [RAC 2-110(1)(h) and RAC 2-118]

1.1.1. An annual operating permit emission fee shall be paid to the Tribe by the

permittee.

[RAC 2-118(2)]

1.1.2. The permittee shall pay the annual permit fee each year no later than April 1 st for

the preceding calendar year.

[RAC 2-118(2)]

1.1.3. Fee payments shall be remitted in the form of a money order, bank draft, certified

check, corporate check, or electronic funds transfer payable to the Southern Ute

Indian Tribe and sent or delivered by the United States Postal Service c/o

Environmental Programs Department Part 70 Program, P.O. Box 737 MS #84,

Ignacio, Colorado 81137; or by common carrier (such as UPS or FedEx) c/o

Environmental Programs Department Part 70 Program, 398 Ouray Drive, Ignacio,

Colorado 81137.

[RAC 2-118(4)(a)]

1.1.4. The permittee shall send an updated fee calculation worksheet submitted annually

by the same deadline as required for fee payment to the address listed in the

Submissions section of this permit.

[RAC 2-118]

1.1.5. The permittee shall submit the initial fee calculation work sheet using the most

recent form provided by the Tribe.

[RAC 2-118(2)(c)]

1.1.6. Basis for calculating annual fee:

1.1.6.1.

Subtotal annual fees shall be calculated by multiplying the applicable

emission fee set pursuant to RAC §2-119(1) of this code times the total

tons of actual emissions for each fee pollutant. In lieu of actual emissions,

annual fees may be calculated based on the potential to emit for each fee

pollutant. Emissions of any regulated air pollutant that already are

included in the fee calculation under a category of regulated pollutant,

such as a federally listed hazardous air pollutant that is already accounted

for as a VOC or as PM10, shall be counted only once in determining the

source’s actual emissions.

[RAC 2-119(2)(a)]

1.1.6.1.1.

“Actual emissions” means the actual rate of emissions in tpy of

any fee pollutant (for fee calculation) emitted from a Title V

source over the preceding calendar year or any other period

determined by the Tribe to be more representative of normal

operation and consistent with the fee schedule adopted by the Tribe

and approved by the Administrator. Actual emissions shall be

calculated using each emissions units actual operating hours,

production rates, in-place control equipment, and types of

materials processed, stored, or combusted during the preceding

calendar year or other period used for this calculation.

[RAC 1-103(2)]

1.1.6.1.2.

Actual emissions shall be computed using compliance methods

required by the permit.

[RAC 2-118(1)(b)]

1.1.6.1.3.

If actual emissions cannot be determined using the compliance

methods in the permit, the permittee shall use other federally

recognized procedures.

[RAC 2-118(1)(b)]

1.1.6.2.

The total annual fee submitted shall be the greater of the applicable

minimum fee or the sum of subtotal annual fees for all fee pollutants

emitted from the source.

[RAC 2-119(2)(b)]

[Explanatory note: The applicable emission fee amount and applicable minimum fee (if necessary)

are revised each calendar year to account for inflation, and they are available from AQD prior to

the start of each calendar year.]

1.1.6.3.

The permittee shall exclude the following emissions from the calculation

of fees:

1.1.6.3.1.

The amount of actual emissions of any one fee pollutant that the

source emits in excess of 4,000 tpy.

1.1.6.3.2.

Any emissions that come from insignificant activities not required

in a permit application pursuant to RAC §2-106(4).

[RAC 1-103(2)(c)]

1.1.7. Annual fee calculation worksheets shall be certified as to truth, accuracy, and

completeness by a responsible official.

[RAC 2-105 and RAC 2-118(2)(c)]

1.1.8. Failure of the permittee to pay fees by the due date shall subject the permittee to

assessment of penalties and interest in accordance with RAC §2-118(6).

[RAC 2-118(6)]

1.1.9. When notified by the Tribe of underpayment of fees, the permittee shall remit full

payment within 30 days of receipt of an invoice from the Tribe.

[RAC 2-119(3)(b)]

1.1.10. A permittee who thinks a Tribe assessed fee is in error and who wishes to

challenge such fee shall provide a written explanation of the alleged error to the

Tribe along with full payment of the assessed fee.

[RAC 2-119(3)(c)]

1.2. Compliance Requirements

1.2.1. Compliance with the Permit

1.2.1.1.

The permittee must comply with all conditions of this part 70 permit. Any

permit noncompliance with federally enforceable or Commission-only

permit conditions constitutes a violation of the RAC and Clean Air Act

and is grounds for enforcement action; for permit termination, revocation

and reissuance, or revision; or for denial of a permit renewal application.

[RAC 2-110(3)(a)]

1.2.1.2.

It shall not be a defense for a permittee in an enforcement action that it

would have been necessary to halt or reduce the permitted activity in order

to maintain compliance with the conditions of this permit.

[RAC 2-110(3)(b)]

1.2.1.3.

All terms and conditions of this permit which are required under the Clean

Air Act or under any of its applicable requirements, including any

provisions designed to limit a source’s potential to emit, are enforceable

by the Administrator and citizens under the Clean Air Act, except terms

and conditions the permit specifically designates as not being federally

enforceable under the Clean Air Act that are not required under the Clean

Air Act or under any of its applicable requirements. Terms and conditions

so designated are not subject to the requirements of RAC §§2-108, 2-111,

2-112, other than those contained in this paragraph.

[RAC 2-110(3)(f)]

1.2.1.4.

This permit, or the filing or approval of a compliance plan, does not

relieve any person from civil or criminal liability for failure to comply

with the provisions of the RAC and the Clean Air Act, applicable

regulations thereunder, and any other applicable law or regulation.

[RAC 2-110(3)(g)]

1.2.1.5.

For the purpose of submitting compliance certifications in accordance

with the Compliance Certifications condition below of this permit, or

establishing whether or not a person has violated or is in violation of any

requirement of this permit, nothing shall preclude the use, including the

exclusive use, of any credible evidence or information, relevant to whether

a source would have been in compliance with applicable requirements if

the appropriate performance or compliance test or procedure had been

performed.

[Section 113(a) and 113(e)(1) of the Act, 40 CFR §§51.212, 52.12, 52.33, 60.11(g), and 61.12]

1.2.2. Compliance Certifications

1.2.2.1.

The permittee shall submit to the Tribe and the Administrator an annual

certification of compliance which shall certify the source’s compliance

status with all permit terms and conditions and all applicable requirements

relevant to the source, including those related to emission limitations,

standards, or work practices. The compliance certification shall be

certified as to truth, accuracy, and completeness by a responsible official

consistent with RAC §2-110(9)(a). The certification of compliance shall

be submitted annually by April 1st and shall cover the preceding calendar

year in which the certification of compliance is due, except that the first

annual certification of compliance will cover the period from the issuance

date of this permit through December 31st of the same year.

[RAC 2-110(9)(c)]

1.2.3. Compliance Schedule

1.2.3.1.

For applicable requirements with which the source is in compliance, the

source will continue to comply with such requirements.

[RAC 2-106(4)(l)(ii)]

1.2.3.2.

For applicable requirements that will become effective during the permit

term, the source shall meet such requirements on a timely basis.

[RAC 2-106(4)(l)(iii)]

1.3. Duty to Provide and Supplement Information [RAC 2-110(7)(e), 2-106(5), and 2124]

1.3.1. The permittee shall furnish to the Tribe, within the period specified by the Tribe,

any information that the Tribe request in writing to determine whether cause

exists for reopening and revising, revoking, and reissuing, or terminating the

permit, or to determine compliance with the permit. Upon request, the permittee

shall also furnish to the Tribe copies of records that are required to be kept by the

permit, including information claimed to be confidential. Information claimed to

be confidential must be accompanied by a claim of confidentiality according to

the provisions of RAC 2-124.

[RAC 2-110(7)(e) and RAC 2-124]

1.3.2. The permittee, upon becoming aware that any relevant facts were omitted or

incorrect information was submitted in the permit application or in a supplemental

submittal, shall promptly submit such supplementary facts or corrected

information. In addition, a permittee shall provide additional information as

necessary to address any requirements that become applicable after the date a

complete application is filed, but prior to release of a draft permit.

[RAC 2-106(5)]

1.4. Submissions [RAC 2-105]

1.4.1. Any application, form, report, compliance certification, or other document

submitted by the permittee under this permit shall contain a certification by a

responsible official of truth, accuracy, and completeness. This certification shall

state that, based on information and belief formed after reasonable inquiry, the

statements and information in the document are true, accurate, and complete.

[Explanatory Note: The Tribe has developed a reporting form “CTAC” for certifying

truth, accuracy and completeness of part 70 submissions. The form may be found on the

AQD’s website (http://www.southernute-nsn.gov/environmental-programs/air-quality).]

1.4.2. Except where otherwise noted, any documents required to be submitted under this

permit, including reports, test data, monitoring data, notifications, compliance

certifications, fee calculation worksheets, and applications for renewals and

permit modifications shall be submitted:

1.5. Severability Clause [RAC 1-106 and RAC 2-110(1)(f)]

by email at: airquality@southernute-nsn.gov

or by United States Postal Service:

Part 70 Program

Environmental Programs Department

Air Quality Division

P.O. Box 737 MS #84

Ignacio, Colorado 81137

or by Common Carrier:

Part 70 Program

Environmental Programs Department

Air Quality Division

398 Ouray Drive

Ignacio, CO 81137

The provisions of this permit are severable, and in the event of any challenge to any portion

of this permit, or if any provision is held invalid, the remaining permit conditions shall

remain valid and in force.

1.6. Permit Actions [RAC 2-110(3)]

1.6.1. This permit may be modified, reopened and revised, revoked and reissued, or

terminated for cause.

[RAC 2-110(3)(c)]

1.6.2. The filing by the permittee of a request for a permit revision, reissuance, or

termination, or of a notification of planned changes or anticipated noncompliance

shall not stay any permit condition.

[RAC 2-110(3)(d)]

1.7. Administrative Permit Revision [RAC 2-111(2)]

1.7.1. The permittee may submit an application for an administrative permit revision as

defined in RAC §1-103.

[RAC 2-111(2)(a)]

1.7.2. The permittee may implement an administrative permit revision immediately

upon submittal of the request for the administrative revision.

[RAC 2-111(2)(c)]

[Note to permittee: If the provisions allowing for an administrative permit revision do not apply,

please contact the Air Quality Division for a determination of similarity prior to submitting your

request for an administrative permit revision.]

1.8. Minor Permit Revisions [RAC 2-111(3)]

1.8.1. The permittee may submit an application for a minor permit revision as defined in

RAC §1-103.

1.8.2. An application requesting the use of minor permit revision procedures shall meet

the requirements of RAC §2-106(4) and shall include the following:

1.8.2.1.

A description of the change, the emissions resulting from the change, and

any new applicable requirements that will apply if the change occurs;

1.8.2.2.

If changes are requested to the permit language, the permittee’s suggested

draft permit changes;

1.8.2.3.

Certification by a responsible official, consistent with RAC §2-105, that

the proposed revision meets the criteria for use of minor permit revision

procedures and a request that such procedures be used; and

1.8.2.4.

Completed forms for the Tribe to use to notify the Administrator and

affected programs as required under RAC §2-108.

1.8.2.5.

If the requested permit revision would affect existing compliance plans or

schedules, related progress reports, or certification of compliance

requirements, and an outline of such effects.

[RAC 2-111(3)(a)]

1.8.3. The permittee shall not submit multiple minor permit revision applications that

may conceal a larger revision that would not constitute a minor permit revision.

[RAC 2-111(3)(b)]

1.8.4. The permittee may make the change proposed in its minor permit revision

application immediately after it files such application, provided, however, for

sources that have previously utilized this provision during the term of the permit

and, on two or more occasions have failed to file a complete application, may

thereafter make the change only after the application is deemed complete. After

the permittee makes the change and until the Tribe takes any of the actions

specified in the following subsection, the permittee must comply with both the

applicable requirements governing the change and the proposed permit terms and

conditions. During this period, the permittee need not comply with the existing

permit terms and conditions it seeks to modify. If the permittee fails to comply

with its proposed permit terms and conditions during this period, however, the

existing permit terms and conditions it seeks to modify may be enforced against

it. The filing of a minor permit revision application does not authorize

construction or modification of a source under the NSR preconstruction permit

program. It is the permittee’s responsibility to determine if a preconstruction

permit is required prior to commencing construction, modification, or

reconstruction.

[RAC 2-111(3)(e)]

1.8.5. The permit shield under RAC §2-110(10) does not extend to minor permit

revisions.

[RAC 2-110(10)(d)]

1.9. Significant Permit Revisions [RAC 2-111(4)]

1.9.1. The permittee must request the use of significant permit revision procedures as

defined in RAC §1-103.

1.9.2. Significant permit revisions shall meet all requirements of the RAC for permit

issuance and renewal, including those for applications, review by the

Administrator and affected programs, and public participation.

[RAC 2-111(4), 2-109, and 2-106(3)]

1.10.

Permit Reopenings, Revocations and Reissuances, and Terminations [RAC 2112]

1.10.1. The permit may be reopened and revised for any of the reasons listed in the

paragraphs below. Alternatively, the permit may be revoked and reissued for the

reasons listed in the paragraphs below:

1.10.1.1.

Additional requirements under the Clean Air Act become applicable to a

major source with a remaining permit term of 3 or more years, provided

that the Tribe shall revise such permits to incorporate such additional

requirements no later than 18 months after promulgation of such

requirements, and no such reopening is required if the effective date of the

requirement is later than the permit expiration date unless the original

permit or any of its terms or conditions have been extended past the permit

expiration date pursuant to RAC §2-104(2)(b)(iii);

1.10.1.2.

Additional requirements (including excess emissions requirements)

become applicable to an affected source under the acid rain program.

Upon approval by the Administrator, excess emissions offset plans shall

be deemed to be incorporated into the permit;

1.10.1.3.

The Tribe or the Administrator determines that the permit contains a

material mistake or that inaccurate statements were made in establishing

the terms or conditions of the permit; or

1.10.1.4.

The Tribe or the Administrator determines that the permit must be revised

or revoked and reissued to assure compliance with applicable

requirements.

1.10.2. The permit may be terminated for any of the reasons listed below:

1.10.2.1.

The permittee fails to meet the requirements of an approved compliance

plan;

1.10.2.2.

The permittee has been in significant or repetitious noncompliance with

the operating permit terms or conditions;

1.10.2.3.

The permittee has exhibited a history of willful disregard for

environmental laws of any tribal or state authority, or of the United States;

1.10.2.4.

The permittee has knowingly misrepresented a material fact in any

application, record, report, plan, or other document filed or required to be

maintained under the permit;

1.10.2.5.

The permittee falsifies, tampers with, or renders inaccurate any monitoring

device or method required to be maintained under the permit;

1.10.2.6.

The permittee fails to pay fees required under RAC§§2-118 and 2-119; or

1.10.2.7.

1.11.

The Administrator has found that cause exists to terminate the permit.

Property Rights [RAC 2-110(3)(e)]

This permit does not convey any property rights of any sort, or any exclusive privilege.

1.12.

Inspection and Entry [RAC 2-110(9)(b)]

Upon presentation of credentials and other documents as may be required by law, the

permittee shall allow authorized representatives of the Tribe or other authorized

representative to perform the following:

1.12.1. Enter upon the permittee’s premises where a source is located or emissionsrelated activity is conducted, or where records must be kept under the conditions

of the permit;

1.12.2. Have access to and copy, at reasonable times, any records that must be kept under

the conditions of the permit;

1.12.3. Inspect at reasonable times any facilities, equipment (including monitoring and air

pollution control equipment), practices, or operations regulated or required under

the permit; and

1.12.4. As authorized by the Clean Air Act, sample or monitor at reasonable times

substances or parameters for the purpose of assuring compliance with the permit

or applicable requirements.

1.13.

[Reserved]

1.14.

Permit Transfers [RAC 2-113]

1.14.1. This permit shall not be transferable, by operation of law or otherwise, from one

location to another or from one source to another, except that a permit may be

transferred from one location to another in the case of a portable source that has

notified the Tribe in advance of the transfer, pursuant to the RAC. A permit for a

source may be transferred from one person to another if the Tribe finds that the

transferee is capable of operating the source in compliance with the permit. This

transfer must be accomplished through an administrative permit revision in

accordance with the Administrative Permit Revisions section of this permit.

1.15.

Off-Permit Changes [RAC 2-116(2)]

1.15.1. The permittee is allowed to make, without a permit revision, certain changes that

are not addressed or prohibited by this permit provided that the following

requirements are met:

1.15.1.1.

Each such change meets all applicable requirements and shall not violate

any existing permit term or condition;

1.15.1.2.

Such changes are not subject to any requirements under title IV of the

Clean Air Act and are not modifications under title I of the Clean Air Act;

1.15.1.3.

Such changes are not subject to permit revision procedures under RAC §2111; and

1.15.1.4.

The permittee provides contemporaneous written notice to the Tribe and

the Administrator of each such change, except for changes that qualify as

insignificant activities. Such notice shall state when the change occurred

and shall describe the change, any resulting emissions change, pollutants

emitted, and any applicable requirement that would apply as a result of the

change.

[RAC 2-116(2)(a)]

1.15.2. The permit shield does not apply to changes made under this provision.

[RAC 2-110(10)(d)]

1.15.3. The permittee shall keep a record describing changes made at the source that

result in emissions of any regulated air pollutant subject to an applicable

requirement, but not otherwise regulated under the permit, and the emissions

resulting from those changes.

[RAC 2-116(2)(b)]

1.15.4. A copy of each off-permit change notification shall be made available to the Tribe

upon request.

[RAC 2-110(6)]

1.16.

Permit Expiration and Renewal

[RAC §§2-104(3), 2-106(2)(b), 2-107(7)(a), 2-107(7)(b), 2-110(1)(a), and 2-106(3)]

1.16.1. This permit shall expire five years from the issuance date of this permit.

[RAC 2-110(1)(a)]

1.16.2. Expiration of this permit terminates the permittee’s right to operate unless a

timely and complete permit renewal application has been submitted at least 6

months but not more than 18 months prior to the date of expiration of this permit.

[RAC 2-107(7)(b)]

1.16.3. If the permittee submits a timely and complete permit application for renewal,

consistent with RAC §2-106 but the Tribe has failed to issue or disapprove a

renewal permit before the end of the permit term, then the permit shall not expire

and all its terms and conditions shall remain in effect until the renewal permit has

been issued or disapproved.

[RAC 2-104(2)(b)]

1.16.4. The ability to operate under this permit shall cease if (1) the Tribe takes final

action to issue the permittee a renewal permit or deny the permittee a permit or

(2) the permittee fails to submit by the deadline specified in writing by the Tribe

any additional information identified as being needed to process the application.

[RAC 2-104(3)]

1.16.5. Renewal of this permit is subject to the same procedures, including those for

public participation and affected program and EPA review, as those that apply to

initial permit issuance.

[RAC 2-107(7)(a)]

1.16.6. The application for renewal shall include the current permit number, description

of permit revisions and off permit changes that occurred during the permit term,

any applicable requirements that were promulgated and not incorporated into the

permit during the permit term, and other information required by the application

form.

[RAC 2-106(4)(e)(ix)]

Facility-Wide Requirements

Conditions in this section of the permit apply to all emissions units located at the facility, including

any units not specifically listed in Table 1 or Table 2 of the Source Emission Points section of this

permit.

[RAC 2-110(1)(d)]

2.1. General Recordkeeping Requirements [RAC 2-110(6)]

The permittee shall comply with the following generally applicable recordkeeping

requirements:

2.1.1. If the permittee determines that his or her stationary source that emits (or has the

potential to emit, without federally recognized controls) one or more hazardous

air pollutants is not subject to a relevant standard or other requirement established

under 40 CFR part 63, the permittee shall keep a record of the applicability

determination, for a period of five years after the determination, or until the

source changes its operations to become an affected source, whichever comes

first. Each of these records shall be made available to the Tribe upon request. The

record of the applicability determination shall include an analysis (or other

information) that demonstrates why the permittee believes the source is

unaffected (e.g., because the source is an area source).

[40 CFR 63.10(b)(3)]

2.1.2. Records shall be kept of off permit changes made, as required by the Off Permit

Changes section of this permit.

2.2. General Reporting Requirements

2.2.1. The permittee shall submit to the Tribe all reports of any required monitoring

under this permit semiannually, by April 1 and October 1 of each year. The

report due on April 1 shall cover the July 1 - December 31 reporting period of the

previous calendar year. The report due on October 1 shall cover the January 1 June 30 reporting period of the current calendar year. All instances of deviations

from permit requirements shall be clearly identified in such reports. All required

reports shall be certified by a responsible official consistent with the Submissions

section of this permit.

[RAC 2-110(7)(a)]

2.2.2. “Deviation” means any situation in which an emissions unit fails to meet a permit

term or condition. A deviation is not always a violation. A deviation can be

determined by observation or through review of data obtained from any testing,

monitoring, or recordkeeping established in accordance with RAC 2-110(5) and

(6). For a situation lasting more than 24 hours which constitutes a deviation, each

24 hour period is considered a separate deviation. Included in the meaning of

deviation are any of the following:

2.2.2.1.

A situation where emissions exceed an emission limitation or standard;

2.2.2.2.

A situation where process or emissions control device parameter values

indicate that an emission limitation or standard has not been met; or

2.2.2.3.

A situation in which observations or data collected demonstrate

noncompliance with an emission limitation or standard or any work

practice or operating condition required by the permit.

2.2.2.4.

A situation in which an exceedance or an excursion, as defined in 40 CFR

Part 64 occurs.

[RAC 1-103(21)]

2.2.3. The permittee shall promptly report to the Tribe deviations from permit

requirements, (including emergencies), including the date, time, duration, and the

probable cause of such deviations, the quantity and pollutant type of excess

emissions resulting from the deviation, and any preventative, mitigation, or

corrective actions or measures taken. Prompt deviation reports shall be submitted

to the following email address: airquality@southernute-nsn.gov

2.2.4.

“Prompt” is defined as follows:

2.2.4.1.

Where the underlying applicable requirement contains a definition of

“prompt” or otherwise specifies a time frame for reporting deviations, that

definition or time frame shall govern.

2.2.4.2.

Where the underlying applicable requirement fails to address the time

frame for reporting deviations, reports of deviations will be submitted

based on the following schedule:

2.2.4.2.1.

For emissions of a hazardous air pollutant or a toxic air pollutant

(as identified in the applicable regulation) that continue for more

than an hour in excess of permit requirements, the report must be

made by email, telephone, verbal, or facsimile communication by

the close of business the next working day, upon discovery of the

occurrence, and in writing within 10 working days from the

occurrence;

2.2.4.2.2.

For emissions of any regulated air pollutant, excluding those listed

in RAC §2-110(7)(b)(i), that continue for more than 2 hours in

excess of permit requirements, the report must be made by email,

telephone, verbal, or facsimile communication by the close of

business the next working day, upon discovery of the occurrence,

and in writing within 10 working days from the occurrence;

2.2.4.2.3.

For all other deviations from permit requirements, the report shall

be contained in the report submitted with the semi-annual

monitoring report.

[RAC 2-110(7)(b)]

2.3. Alternative Operating Scenarios [RAC 2-110(8)]

2.3.1. Replacement of an existing engine or turbine identified in this permit shall be

allowed as an off-permit change pursuant to the Off Permit Changes provisions of

this permit provided all of the following conditions are met:

2.3.1.1.

The engine or turbine replacement is not subject to any requirements

under Title IV of the Clean Air Act and is not a modification under Title I

of the Clean Air Act;

2.3.1.2.

The replacement engine or turbine is of the same make, model,

horsepower rating, and configured to operate in the same manner as the

engine or turbine being replaced.

2.3.1.3.

The replacement engine or turbine meets all applicable requirements

identified in this permit that apply to the existing engine or turbine being

replaced.

2.3.1.4.

All applicable requirements that apply to the replacement engine or

turbine are already included in the permit. Replacement of an existing

engine or turbine identified in this permit with a new, modified, or

reconstructed engine must utilize a Minor Permit Revision as specified in

RAC 2-111(3) or a Significant Permit Revision as specified in RAC 2111(4) to incorporate any new applicable requirements. The applicable

requirements include, but may not be limited to:

2.3.1.4.1.

Standards of Performance for Stationary Compression Ignition

Internal Combustion at 40 CFR Part 60, Subpart IIII;

2.3.1.4.2.

Standards of Performance for Stationary Spark Ignition Internal

Combustion Engines at 40 CFR Part 60, Subpart JJJJ;

2.3.1.4.3.

National Emission Standard for Hazardous Air Pollutants for

Stationary Reciprocating Internal Combustion Engines at 40 CFR

Part 63, Subpart ZZZZ;

2.3.1.4.4.

Standards of Performance for Stationary Gas Turbines at 40 CFR

Part 60, Subpart GG;

2.3.1.4.5.

Standards of Performance for Stationary Combustion Turbines at

40 CFR Part 60, Subpart KKKK;

2.3.1.4.6.

National Emission Standard for Hazardous Air Pollutants for

Stationary Combustion Turbines at 40 CFR Part 63, Subpart

YYYY;

2.3.1.4.7.

Requirements established in a permit or permits issued pursuant to

the Federal Minor New Source Review Program in Indian Country

at 40 CFR Part 49;

2.3.1.4.8.

Requirements established in a permit or permits issued pursuant to

the Prevention of Significant Deterioration of Air Quality Program

at 40 CFR Part 52; or

2.3.1.4.9.

Requirements established in any promulgated Federal

Implementation Plan that may apply to engines located on the

Southern Ute Indian Reservation.

2.3.2. The permittee shall provide contemporaneous written notice to the Tribe and the

Administrator of any replacement of an existing engine or turbine identified in

this permit. Such notice shall state when the replacement occurred and shall

describe the replacement and any applicable requirement that would apply as a

result of the replacement.

2.3.3. The permittee shall keep a record of the engine or turbine replacement.

2.3.4. The use of a backup thermal oxidizer with equivalent capacity and emission

destruction efficiency and configured to operate in the same manner as the

primary thermal oxidizer shall be an allowed alternative operating scenario under

this permit provided that the following conditions are met:

2.3.4.1.

Any emission limits, requirements, testing or other provisions that apply to

the primary thermal oxidizer shall also apply to the backup thermal

oxidizer except that an annual performance test shall only be conducted on

the backup thermal oxidizer if the unit operates for more than 500 hours in

any calendar year.

2.3.4.2.

At no time shall the backup thermal oxidizer operate at the same time the

primary thermal oxidizer is operating except periods of transition between

the primary and backup thermal oxidizers. Transition events shall be

documented, last no more than 30 minutes in duration, and will be

reported as excess emission events.

2.4. Permit Shield [RAC 2-110(10)(c)]

Nothing in this permit shall alter or affect the following:

2.4.1. The provisions of Section 303 of the Clean Air Act, 42 U.S.C. §7603 concerning

emergency powers, including the respective authorities of the Administrator under

those sections;

2.4.2. The liability of a permittee for any violation of applicable requirements prior to or

at the time of permit issuance;

2.4.3. The applicable requirements of the acid rain program consistent with section

408(a) of the Act; or

2.4.4. The ability of the Administrator respectively to obtain information from a source

pursuant to Section 114 of the Clean Air Act, 42 U.S.C. §7414.

2.5. Stratospheric Ozone and Climate Protection [40 CFR Part 82]

The permittee shall comply with the standards for recycling and emissions reduction

pursuant to 40 CFR Part 82, Subpart F:

2.5.1. Persons opening appliances for maintenance, service, repair, or disposal must

comply with the required practices pursuant to 40 CFR §82.156.

2.5.2. Equipment used during the maintenance, service, repair, or disposal of appliances

must comply with the standards for recycling and recovery equipment pursuant to

40 CFR §82.158.

2.5.3. Persons performing maintenance, service, repair, or disposal of appliances must

be certified by an approved technician certification program pursuant to 40 CFR

§82.161.

Section III – Site Specific Permit Terms

New Source Performance Standards (NSPS) and 40 CFR Part 60

1.1. 40 CFR Part 60, Subpart OOOOb – Standards of Performance for Crude Oil and

Natural Gas Facilities for Which Construction, Modification or Reconstruction

Commenced After December 6, 2022 [40 CFR 60.5360b - 60.5439b]

This facility is subject to the requirements of 40 CFR Part 60, Subpart OOOOb for the

collection of fugitive emissions components at a compressor station. Notwithstanding

conditions in this permit, the permittee shall comply with all applicable requirements of

40 CFR Part 60, subparts A and OOOOb.

1.1.1. Affected Sources

The following emission units are considered affected sources under 40 CFR Part

60, Subpart OOOOb:

The collection of fugitive emission components at a compressor station located at

Trail Canyon Compressor Station.

[40 CFR 60.5365b(i)(3)(i)]

1.1.2. General Requirements

1.1.2.1.

At all times, including periods of startup, shutdown, and malfunction,

owners and operators shall maintain and operate any affected facility

including associated air pollution control equipment in a manner

consistent with good air pollution control practice for minimizing

emissions. Determination of whether acceptable operating and

maintenance procedures are being used will be based on information

available to the Administrator which may include, but is not limited to,

monitoring results, opacity observations, review of operating and

maintenance procedures, and inspection of the source. The provisions for

exemption from compliance during the periods of startup, shutdown and

malfunctions provided for in 40 CFR 60.8(c) do not apply to this subpart.

[40 CFR 60.5370b(b)]

1.1.3. Super-Emitter Events

The provisions of this section will not apply between July 31, 2025, and

January 22, 2027. The provisions of this section will apply after January 22,

2027. This section applies to super-emitter events. For purposes of this

section, a super-emitter event is defined as any emissions event that is located

at or near an oil and natural gas facility (e.g., individual well site, centralized

production facility, natural gas processing plant, or compressor station) and

that is detected using remote detection methods and has quantified emission

rate of 100 kg/hr of methane or greater. §60.5371b(a) describes the

qualifications one must meet to apply to be a third-party notifier of superemitter events. §60.5371b(b) describes the procedures for certifying thirdparty notifiers, as well as the procedures for petitioning the Agency for

removal of a third-party notifier from the list of certified notifiers.

§60.5371b(c) contains the required information that must be included in any

notification submitted to the EPA from a certified third-party notifier and a

timetable for notifications. The EPA shall review these notifications and if the

EPA determines the notification is complete and does not contain information

that the EPA finds to be erroneous or inaccurate to a reasonable degree of

certainty, the EPA shall assign the notification a unique notification

identification number, provide the notification to the owner or operator of the

oil and natural gas facility identified in the notification, and post the

notification, except for the owner/operator attribution, at www.epa.gov/superemitter. Upon receiving such notification, owners or operators must take the

actions listed in §60.5371b(d) and (e). The EPA shall post the reports

submitted under §60.5371b(e), §60.5371(b) and §60.5371a(b) of subparts

OOOO and OOOOa of this part, and applicable State or Federal plan

implementing §60.5388c(b) of subpart OOOOc of this part, including

owner/operator attributions that have been confirmed by the reports; where the

reporting deadlines have passed but no reports have been received, the EPA

intends to post owner/operator attributions that the EPA reasonably believes to

be accurate. The reports will be publicly available at www.epa.gov/superemitter.

[40 CFR 60.5371b]

1.1.3.1.

Identification of super-emitter events. Within 5 calendar days of

receiving a notification from the EPA of a super-emitter event, the owner

or operator of an oil and natural gas facility (e.g., a well site, centralized

production facility, natural gas processing plant, or compressor station)

must initiate a super-emitter event investigation. The investigation must be

conducted in accordance with this paragraph §60.5371b(d) and completed

within 15 days of receiving the notification from the EPA. The owner or

operator must maintain records of its super-emitter event investigations

and report the findings from the investigation according to the

requirements in §60.5371b(e).

[40 CFR 60.5371b(d)]

1.1.3.1.1. If you do not own or operate an oil and natural gas facility

within 50 meters from the latitude and longitude provided in

the notification, report this result to the EPA under

§60.5371b(e). Your super-emitter event investigation is

deemed complete.

[40 CFR 60.5371b(d)(1)]

1.1.3.1.2. If you own or operate an oil and natural gas facility within 50

meters from the latitude and longitude provided in the

notification, you must investigate to determine the source of

super-emitter event. The investigation may include but is not

limited to the actions specified below in §60.5371b(d)(2)(i)

through (v).

[40 CFR 60.5371b(d)(2)]

1.1.3.1.2.1. Review any maintenance activities (e.g., liquids

unloading) or process activities from the affected

facilities subject to regulation under this subpart, starting

from the date of detection of the super-emitter event as

identified in the notification, until the date of

investigation, to determine if the activities indicate any

potential source(s) of the super-emitter event emissions.

[40 CFR 60.5371b(d)(2)(i)]

1.1.3.1.2.2. Review all monitoring data from control devices (e.g.,

flares) from the affected facilities subject to regulation

under this subpart from the initial date of detection of the

super-emitter event as identified in the notification until

the date of receiving the notification from the EPA.

Identify any malfunctions of control devices or periods

when the control devices were not in compliance with

applicable requirements and that indicate a potential

source of the super-emitter event emissions.

[40 CFR 60.5371b(d)(2)(ii)]

1.1.3.1.2.3. If you conducted a fugitive emissions survey or periodic

screening event in accordance with §60.5397b or

§60.5398b(b) between the initial date of detection of the

super-emitter event as identified in the notification and

the date the notification from the EPA was received,

review the results of the survey to identify any potential

source(s) of the super-emitter event emissions.

[40 CFR 60.5371b(d)(2)(iii)]

1.1.3.1.2.4. If you conduct continuous monitoring with advanced

methane detection technology in accordance with

§60.5398b(c), review the monitoring data collected on or

after the initial date of detection of the super-emitter

event as identified in the notification, until the date of

receiving the notification from the EPA.

[40 CFR 60.5371b(d)(2)(iv)]

1.1.3.1.2.5. Screen the entire oil and natural gas facility with OGI,

Method 21 of appendix A-7 to this part, or an alternative

test method(s) approved per §60.5398b(d), to determine if

a super-emitter event is present.

[40 CFR 60.5371b(d)(2)(v)]

1.1.3.1.3. If the source of the super-emitter event was found to be from

fugitive emission components at a well site, centralized

production facility, or compressor station subject to this

subpart, you must comply with the repair requirements under

§60.5397b and the associated recordkeeping and reporting

requirements under §60.5420b(b)(9) and (c)(14).

[40 CFR 60.5371b(d)(3)]

1.1.3.2.

Super-emitter event report. You must submit the results of the superemitter event investigation conducted under §60.5371b(d) to the EPA in

accordance with §60.5371b(e)(1). If the super-emitter event (i.e., emission

at 100 kg/hr of methane or more) is ongoing at the time of the initial

report, submit the additional information in accordance with

§60.5371b(e)(2). You must attest to the information included in the report

as specified in §60.5371b(e)(3).

[40 CFR 60.5371b(e)]

1.1.3.2.1. Within 15 days of receiving a notification from the EPA under

§60.5371b(c), you must submit a report of the super-emitter

event investigation conducted under §60.5371b(d) through the

Super-Emitter Program Portal. You must include the applicable

information in §60.5371b(e)(1)(i) through (viii) in the report. If

you have identified a demonstrable error in the notification, the

report may include a statement of the demonstrable error.

[40 CFR 60.5371b(e)(1)]

1.1.3.2.1.1. Notification Report ID of the super-emitter event

notification.

[40 CFR 60.5371b(e)(1)(i)]

1.1.3.2.1.2. Identification of whether you are the owner or operator of

an oil and natural gas facility within 50 meters from the

latitude and longitude provided in the EPA notification. If

you do not own or operate an oil and natural gas facility

within 50 meters from the latitude and longitude provided

in the EPA notification, you are not required to report the

information in §60.5371b(e)(1)(iii) through (viii).

[40 CFR 60.5371b(e)(1)(ii)]

1.1.3.2.1.3. General identification information for the facility,

including, facility name, the physical address, applicable

ID Number (e.g., EPA ID Number, API Well ID

Number), the owner or operator or responsible official

(where applicable) and their email address.

[40 CFR 60.5371b(e)(1)(iii)]

1.1.3.2.1.4. Identification of whether there is an affected facility or

associated equipment subject to regulation under this

subpart at this oil and natural gas facility.

[40 CFR 60.5371b(e)(1)(iv)]

1.1.3.2.1.5. Indication of whether you were able to identify the source

of the super-emitter event. If you indicate you were

unable to identify the source of the super-emitter event,

you must certify that all applicable investigations

specified in §60.5371b(d)(2)(i) through (v) have been

conducted for all affected facilities and associated

equipment subject to this subpart that are at this oil and

natural gas facility, and you have determined that the

affected facilities and associated equipment are not the

source of the super-emitter event. If you indicate that you

were not able to identify the source of the super-emitter

event, you are not required to report the information in

§60.5371b(e)(1)(vi) through (viii).

[40 CFR 60.5371b(e)(1)(v)]

1.1.3.2.1.6. The source(s) of the super-emitter event.

[40 CFR 60.5371b(e)(1)(vi)]

1.1.3.2.1.7. Identification of whether the source of the super-emitter

event is equipment subject to regulation under this

subpart. If the source of the super-emitter event is

equipment subject to regulation under this subpart,

identify the applicable regulation(s) under this subpart.

[40 CFR 60.5371b(e)(1)(vii)]

1.1.3.2.1.8. Indication of whether the super-emitter event is ongoing

at the time of the initial report submittal (i.e., emissions at

100 kg/hr of methane or more).

[40 CFR 60.5371b(e)(1)(viii)]

1.1.3.2.1.8.1. If the super-emitter event is not ongoing at the

time of the initial report submittal, provide the

actual (or if unknown) estimated date and time

the super-emitter event ended.

[40 CFR 60.5371b(e)(1)(viii)(A)]

1.1.3.2.1.8.2. If the super-emitter event is ongoing at the time

of the initial report submittal, provide a short

narrative of your plan to end the super-emitter

event, including the targeted end date for the

efforts to be completed and the super-emitter

event ended.

[40 CFR 60.5371b(e)(1)(viii)(B)]

1.1.3.2.2. If the super-emitter event is ongoing at the time of the initial

report submittal, within 5 business days of the date the superemitter event ends, you must update your initial report through

the Super-Emitter Program Portal to provide the end date and

time of the super-emitter event.

[40 CFR 60.5371b(e)(2)]

1.1.3.2.3. You must sign the following attestation when submitting data

into the Super-Emitter Program Portal: “I certify that the

information provided in this report regarding the specified

super-emitter event was prepared under my direction or

supervision. I further certify that the investigations were

conducted, and this report was prepared pursuant to the

requirements of §60.5371b(d) and (e). 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 knowingly false statements may be punishable by fine or

imprisonment.”

[40 CFR 60.5371b(e)(3)]

1.1.4. Standards for Fugitive Emissions Components Affected Facilities

1.1.4.1.

General requirements. You must monitor all fugitive emissions

components affected facilities in accordance with §60.5397b(b) through

(g). You must repair all sources of fugitive emissions in accordance with

§60.5397b(h). You must demonstrate initial compliance in accordance

with §60.5397b(i). You must keep records in accordance with

§60.5397b(j) and report in accordance with §60.5397b(k).

[40 CFR 60.5397b(a)]

1.1.4.2.

Develop fugitive emissions monitoring plan. You must develop a

fugitive emissions monitoring plan that covers all fugitive emissions

components affected facilities within each company-defined area in

accordance with §60.5397b(c) and (d).

[40 CFR 60.5397b(b)]

1.1.4.3.

Elements of fugitive emissions monitoring plan. Your fugitive

emissions monitoring plan must include the elements specified in

§60.5397b(c)(1) through (8), at a minimum.

[40 CFR 60.5397b(c)]

1.1.4.3.1. Frequency for conducting surveys. Surveys must be conducted

at least as frequently as required by §60.5397b(f) and (g).

[40 CFR 60.5397b(c)(1)]

1.1.4.3.2. Technique for determining fugitive emissions (i.e., AVO or

other detection methods, Method 21 of appendix A-7 to this

part, and/or OGI and meeting the requirements of

§60.5397b(c)(7)(i) through (vii)).

[40 CFR 60.5397b(c)(2)]

1.1.4.3.3. Manufacturer and model number of fugitive emissions

detection equipment to be used, if applicable.

[40 CFR 60.5397b(c)(3)]

1.1.4.3.4. Procedures and timeframes for identifying and repairing

fugitive emissions components from which fugitive emissions

are detected, including timeframes for fugitive emission

components that are unsafe to repair. Your repair schedule

must meet the requirements of §60.5397b(h) at a minimum.

[40 CFR 60.5397b(c)(4)]

1.1.4.3.5. Procedures and timeframes for verifying fugitive emission

component repairs.

[40 CFR 60.5397b(c)(5)]

1.1.4.3.6. Records that will be kept and the length of time records will be

kept.

[40 CFR 60.5397b(c)(6)]

1.1.4.3.7. If you are using OGI, your plan must also include the elements

specified in §60.5397b(c)(7)(i) through (vii).

[40 CFR 60.5397b(c)(7)]

1.1.4.3.7.1. Verification that your OGI equipment meets the

specifications of §60.5397b(c)(7)(i)(A) and (B). This

verification is an initial verification, and may either be

performed by the facility, by the manufacturer, or by a

third party. For the purposes of complying with the

fugitive emissions monitoring program with OGI,

fugitive emissions are defined as any visible emissions

observed using OGI.

[40 CFR 60.5397b(c)(7)(i)]

1.1.4.3.7.1.1. Your OGI equipment must be capable of

imaging gases in the spectral range for the

compound of highest concentration n the

potential fugitive emissions.

[40 CFR 60.5397b(c)(7)(i)(A)]

1.1.4.3.7.1.2. Your OGI equipment must be 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/hr from a quarter inch diameter orifice.

[40 CFR 60.5397b(c)(7)(i)(B)]

1.1.4.3.7.2. Procedure for a daily verification check.

[40 CFR 60.5397b(c)(7)(ii)]

1.1.4.3.7.3. Procedure for determining the operator’s maximum

viewing distance from the equipment and how the

operator will ensure that this distance is maintained.

[40 CFR 60.5397b(c)(7)(iii)]

1.1.4.3.7.4. 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.

[40 CFR 60.5397b(c)(7)(iv)]

1.1.4.3.7.5. Procedures for conducting surveys, including the items

specified in §60.5397b(c)(7)(v)(A) through (C).

[40 CFR 60.5397b(c)(7)(v)]

1.1.4.3.7.5.1. How the operator will ensure an adequate

thermal background is present in order to view

potential fugitive emissions.

[40 CFR 60.5397b(c)(7)(v)(A)]

1.1.4.3.7.5.2. How the operator will deal with adverse

monitoring conditions, such as wind.

[40 CFR 60.5397b(c)(7)(v)(B)]

1.1.4.3.7.5.3. How the operator will deal with interferences

(e.g., steam).

[40 CFR 60.5397b(c)(7)(v)(C)]

1.1.4.3.7.6. Training and experience needed prior to performing

surveys.

[40 CFR 60.5397b(c)(7)(vi)]

1.1.4.3.7.7. Procedures for calibration and maintenance. At a

minimum, procedures must comply with those

recommended by the manufacturer.

[40 CFR 60.5397b(c)(7)(vii)]

1.1.4.3.8. If you are using Method 21 of appendix A-7 to this part, your

plan must also include the elements specified in

§60.5397b(c)(8)(i) through (iv). For the purposes of complying

with the fugitive emissions monitoring program using Method

21 of appendix A-7 to this part a fugitive emission is defined as

an instrument reading of 500 ppmv or greater.

[40 CFR 60.5397b(c)(8)]

1.1.4.3.8.1. Verification that your monitoring equipment meets

the requirements specified in Section 6.0 of Method 21

of appendix A-7 to this part. For purposes of instrument

capability, the fugitive emissions definition shall be 500

ppmv or greater methane using a FID-based instrument.

If you wish to use an analyzer other than an FID-based

instrument, you must develop a site-specific fugitive

emission definition that would be equivalent to 500 ppmv

methane using a FID-based instrument (e.g., 10.6 eV PID

with a specified isobutylene concentration as the fugitive

emission definition would provide equivalent response to

your compound of interest).

[40 CFR 60.5397b(c)(8)(i)]

1.1.4.3.8.2. Procedures for conducting surveys. At a minimum, the

procedures shall ensure that the surveys comply with the

relevant sections of Method 21 of appendix A-7 to this

part, including Section 8.3.1.

[40 CFR 60.5397b(c)(8)(ii)]

1.1.4.3.8.3. Procedures for calibration. The instrument must be

calibrated before use each day of its use by the

procedures specified in Method 21 of appendix A-7 to

this part. At a minimum, you must also conduct precision

tests at the interval specified in Method 21 of appendix

A-7 to this part, Section 8.1.2, and a calibration drift

assessment at the end of each monitoring day. The

calibration drift assessment must be conducted as

specified in §60.5397b(c)(8)(iii)(A). Corrective action for

drift assessments is specified in §60.5397b(c)(8)(iii)(B)

and (C).

[40 CFR 60.5397b(c)(8)(iii)]

1.1.4.3.8.3.1. Check the instrument using the same calibration

gas that was used to calibrate the instrument

before use. Follow the procedures specified in

Method 21 of appendix A-7 to this part, Section

10.1, except do not adjust the meter readout to

correspond to the calibration gas value. If

multiple scales are used, record the instrument

reading for each scale used. Divide the

arithmetic difference of the initial and post-test

calibration response by the corresponding

calibration gas value for each scale and multiply

by 100 to express the calibration drift as a

percentage.

[40 CFR 60.5397b(c)(8)(iii)(A)]

1.1.4.3.8.3.2. If a calibration drift assessment shows a

negative drift of more than 10 percent, then all

equipment with instrument readings between the

fugitive emission definition multiplied by (100

minus the percent of negative drift) divided by

100 and the fugitive emission definition that

was monitored since the last calibration must be

re-monitored.

[40 CFR 60.5397b(c)(8)(iii)(B)]

1.1.4.3.8.3.3. If any calibration drift assessment shows a

positive drift of more than 10 percent from the

initial calibration value, then, at the

owner/operator's discretion, all equipment with

instrument readings above the fugitive emission

definition and below the fugitive emission

definition multiplied by (100 plus the percent of

positive drift) divided by 100 monitored since

the last calibration may be re-monitored.

[40 CFR 60.5397b(c)(8)(iii)(C)]

1.1.4.3.8.4. Procedures for monitoring yard piping (other than

buried yard piping). At a minimum, place the probe

inlet at the surface of the yard piping and run the probe

down the length of the piping. Connection points on the

piping must be monitored following the procedures

specified in Method 21 of appendix A-7 to this part.

[40 CFR 60.5397b(c)(8)(iv)]

1.1.4.4.

Additional elements of fugitive emissions monitoring plan. Each

fugitive emissions monitoring plan must include the elements specified in

§60.5397b(d)(1) and (2), at a minimum, as applicable.

[40 CFR 60.5397b(d)]

1.1.4.4.1. If you are using OGI, your plan must include procedures to

ensure that all fugitive emissions components, except buried

yard piping and associated components (e.g., connectors), are

monitored during each survey. Example procedures include,

but are not limited to, a sitemap with an observation path, a

written narrative of where the fugitive emissions components

are located and how they will be monitored, or an inventory of

fugitive emissions components.

[40 CFR 60.5397b(d)(1)]

1.1.4.4.2. If you are using Method 21 of appendix A-7 to this part, your

plan must include a list of fugitive emissions components to be

monitored and method for determining the location of fugitive

emissions components to be monitored in the field (e.g.,

tagging, identification on a process and instrumentation

diagram, etc.). Your fugitive emissions monitoring plan must

include the written plan developed for all of the fugitive

emissions components designated as difficult-to-monitor in

accordance with §60.5397b(g)(2), and the written plan for

fugitive emissions components designated as unsafe-to-monitor

in accordance with §60.5397b(g)(3).

[40 CFR 60.5397b(d)(2)]

1.1.4.5.

Monitoring of fugitive emissions components. Each fugitive emissions

component, except buried yard piping and associated components (e.g.,

connectors), shall be observed or monitored for fugitive emissions during

each monitoring survey.

[40 CFR 60.5397b(e)]

1.1.4.6.

Initial monitoring survey. You must conduct initial monitoring surveys

according to the requirement specified in §60.5397b(f)(3).

[40 CFR 60.5397b(f)]

1.1.4.6.1. For a modified or reconstructed fugitive emissions components

affected facility, the initial monitoring survey must be

conducted within 90 days of the startup of production for each

fugitive emissions components affected facility after the

modification or reconstruction.

[40 CFR 60.5397b(f)(3)]

1.1.4.7.

Monitoring frequency. A monitoring survey of each fugitive emissions

components affected facility must be performed as specified in §60.5397

(g)(1), with the exceptions noted in §60.5397b(g)(2) and (3).

[40 CFR 60.5397b(g)]

1.1.4.7.1. A monitoring survey of the fugitive emissions components

affected facilities must be conducted using the methods and at

the frequencies specified in in §60.5397b(g)(1)(v).

[40 CFR 60.5397b(g)(1)]

1.1.4.7.1.1. A monitoring survey of the fugitive emissions

components affected facility located at a compressor

station must be conducted at the frequencies in

§60.5397b(g)(1)(v)(A) and (B).

[40 CFR 60.5397b(g)(1)(v)]

1.1.4.7.1.1.1. A monitoring survey must be conducted at least

monthly using AVO, or any other detection

method, after the initial survey. Any indications

of fugitive emissions using these methods are

considered fugitive emissions that must be

repaired in accordance with §60.5397b(h).

[40 CFR 60.5397b(g)(1)(v)(A)]

1.1.4.7.1.1.2. A monitoring survey must be conducted at least

quarterly using OGI or Method 21 of appendix

A-7 to this part after the initial survey.

Consecutive quarterly monitoring surveys must

be conducted at least 60 calendar days apart.

[40 CFR 60.5397b(g)(1)(v)(B)]

1.1.4.7.2. If you are using Method 21 of appendix A-7 to this part,

fugitive emissions components that cannot be monitored

without elevating the monitoring personnel more than 2 meters

above the surface may be designated as difficult-to-monitor.

Fugitive emissions components that are designated difficult-tomonitor must meet the specifications of §60.5397b(g)(2)(i)

through (iv).

[40 CFR 60.5397b(g)(2)]

1.1.4.7.2.1. A written plan must be developed for all the fugitive

emissions components designated difficult-to-monitor.

This written plan must be incorporated into the fugitive

emissions monitoring plan required by §60.5397b(b), (c),

and (d).

[40 CFR 60.5397b(g)(2)(i)]

1.1.4.7.2.2. The plan must include the identification and location of

each fugitive emissions component designated as

difficult-to-monitor.

[40 CFR 60.5397b(g)(2)(ii)]

1.1.4.7.2.3. The plan must include an explanation of why each

fugitive emissions component designated as difficult-tomonitor is difficult-to-monitor.

[40 CFR 60.5397b(g)(2)(iii)]

1.1.4.7.2.4. The plan must include a schedule for monitoring the

difficult-to-monitor fugitive emissions components at

least once per calendar year.

[40 CFR 60.5397b(g)(2)(iv)]

1.1.4.7.3. If you are using Method 21 of appendix A-7 to this part,

fugitive emissions components that cannot be monitored

because monitoring personnel would be exposed to immediate

danger while conducting a monitoring survey may be

designated as unsafe-to-monitor. Fugitive emissions

components that are designated unsafe-to-monitor must meet

the specifications of §60.5397b(g)(3)(i) through (iv).

[40 CFR 60.5397b(g)(3)]

1.1.4.7.3.1. A written plan must be developed for all the fugitive

emissions components designated unsafe-to-monitor.

This written plan must be incorporated into the fugitive

emissions monitoring plan required by §60.5397b(b), (c),

and (d).

[40 CFR 60.5397b(g)(3)(i)]

1.1.4.7.3.2. The plan must include the identification and location of

each fugitive emissions component designated as unsafeto-monitor.

[40 CFR 60.5397b(g)(3)(ii)]

1.1.4.7.3.3. The plan must include an explanation of why each

fugitive emissions component designated as unsafe-tomonitor is unsafe-to-monitor.

[40 CFR 60.5397b(g)(3)(iii)]

1.1.4.7.3.4. The plan must include a schedule for monitoring the

fugitive emissions components designated as unsafe-tomonitor.

[40 CFR 60.5397b(g)(3)(iv)]

1.1.4.8.

Repairs. Each identified source of fugitive emissions shall be repaired in

accordance with §60.5397b(h)(1) and (2).

[40 CFR 60.5397b(h)]

1.1.4.8.1. A first attempt at repair shall be made in accordance with

§60.5397b(h)(1)(i) and (ii).

[40 CFR 60.5397b(h)(1)]

1.1.4.8.1.1. A first attempt at repair shall be made no later than 15

calendar days after detection of fugitive emissions that

were identified using AVO.

[40 CFR 60.5397b(h)(1)(i)]

1.1.4.8.1.2. If you are using OGI or Method 21 of appendix A-7 to

this part, a first attempt at repair shall be made no later

than 30 calendar days after detection of the fugitive

emissions.

[40 CFR 60.5397b(h)(1)(ii)]

1.1.4.8.2. Repair shall be completed as soon as practicable, but no later

than 15 calendar days after the first attempt at repair as

required in §60.5397b(h)(1)(i), and 30 calendar days after the

first attempt at repair as required in §60.5397b(h)(1)(ii).

[40 CFR 60.5397b(h)(2)]

1.1.4.8.3. Delay of repair will be allowed if the conditions in

§60.5397b(h)(3)(i) or (ii) are met.

[40 CFR 60.5397b(h)(3)]

1.1.4.8.3.1. If the repair is technically infeasible, would require a vent

blowdown, a compressor station shutdown, a well

shutdown or well shut-in, or would be unsafe to repair

during operation of the unit, the repair must be completed

during the next scheduled compressor station shutdown

for maintenance, scheduled well shutdown, scheduled

well shut-in, after a scheduled vent blowdown, or within

2 years of detecting the fugitive emissions, whichever is

earliest. A vent blowdown is the opening of one or more

blowdown valves to depressurize major production and

processing equipment, other than a storage vessel.

[40 CFR 60.5397b(h)(3)(i)]

1.1.4.8.3.2. If the repair requires replacement of a fugitive emissions

component or a part thereof, but the replacement cannot

be acquired and installed within the repair timelines

specified in §60.5397b(h)(1) and (2) due to either of the

conditions specified in §60.5397b(h)(3)(ii)(A) or (B), the

repair must be completed in accordance with

§60.5397b(h)(3)(ii)(C) and documented in accordance

with §60.5420b(c)(14)(v)(I).

[40 CFR 60.5397b(h)(3)(ii)]

1.1.4.8.3.2.1. Valve assembly supplies had been sufficiently

stocked but are depleted at the time of the

required repair.

[40 CFR 60.5397b(h)(3)(ii)(A)]

1.1.4.8.3.2.2. A replacement fugitive emissions component or

a part thereof requires custom fabrication.

[40 CFR 60.5397b(h)(3)(ii)(B)]

1.1.4.8.3.2.3. The required replacement must be ordered no

later than 10 calendar days after the first attempt

at repair. The repair must be completed as soon

as practicable, but no later than 30 calendar days

after receipt of the replacement component,

unless the repair requires a compressor station

or well shutdown. If the repair requires a

compressor station or well shutdown, the repair

must be completed in accordance with the

timeframe specified in §60.5397b(h)(3)(i).

[40 CFR 60.5397b(h)(3)(ii)(C)]

1.1.4.8.4. Each identified source of fugitive emissions must be

resurveyed to complete repair according to the requirements of

§60.5397b(h)(4)(i) through (v), to ensure that there are no

fugitive emissions.

[40 CFR 60.5397b(h)(4)]

1.1.4.8.4.1. The operator may resurvey the fugitive emissions

components to verify repair using either Method 21 of

appendix A-7 to this part or OGI, except as specified in

§60.5397b(h)(4)(v).

[40 CFR 60.5397b(h)(4)(i)]

1.1.4.8.4.2. For each repair that cannot be made during the

monitoring survey when the fugitive emissions are

initially found, a digital photograph must be taken of that

component, or the component must be tagged during the

monitoring survey when the fugitive emissions were

initially found for identification purposes and subsequent

repair. The digital photograph must include the date that

the photograph was taken and must clearly identify the

component by location within the site (e.g., the latitude

and longitude of the component or by other descriptive

landmarks visible in the picture).

[40 CFR 60.5397b(h)(4)(ii)]

1.1.4.8.4.3. Operators that use Method 21 of appendix A-7 to this part

to resurvey the repaired fugitive emissions components

are subject to the resurvey provisions specified in

§60.5397b(h)(4)(iii)(A) and (B).

[40 CFR 60.5397b(h)(4)(iii)]

1.1.4.8.4.3.1. A fugitive emissions component is repaired

when the Method 21 instrument indicates a

concentration of less than 500 ppmv above

background or when no soap bubbles are

observed when the alternative screening

procedures specified in section 8.3.3 of Method

21 of appendix A-7 to this part are used.

[40 CFR 60.5397b(h)(4)(iii)(A)]

1.1.4.8.4.3.2. Operators must use the Method 21 monitoring

requirements specified in §60.5397b(c)(8)(ii) or

the alternative screening procedures specified in

section 8.3.3 of Method 21 of appendix A-7 to

this part.

[40 CFR 60.5397b(h)(4)(iii)(B)]

1.1.4.8.4.4. Operators that use OGI to resurvey the repaired fugitive

emissions components are subject to the resurvey

provisions specified in §60.5397b(h)(4)(iv)(A) and (B).

[40 CFR 60.5397b(h)(4)(iv)]

1.1.4.8.4.4.1. A fugitive emissions component is repaired

when the OGI instrument shows no indication

of visible emissions.

[40 CFR 60.5397b(h)(4)(iv)(A)]

1.1.4.8.4.4.2. Operators must use the OGI monitoring

requirements specified in §60.5397b(c)(7).

[40 CFR 60.5397b(h)(4)(iv)(B)]

1.1.4.8.4.5. For fugitive emissions identified using AVO detection

methods, the operator may resurvey using those same

methods, Method 21 of appendix A-7 to this part, or OGI.

For operators that use AVO detection methods, a fugitive

emissions component is repaired when there are no

indications of fugitive emissions using these methods.

[40 CFR 60.5397b(h)(4)(v)]

1.1.5. Initial Compliance with the Standards for the Collection of Fugitive

Emissions Components at a Compressor Station.

You must determine initial compliance with the standards for each affected

facility using the requirements of §60.5410b(k). Except as otherwise provided in

this section, the initial compliance period begins on the date specified in

§60.5370b and ends no later than 1 year after that date. The initial compliance

period may be less than 1 full year.

1.1.5.1.

Fugitive emission components affected facility. To achieve initial

compliance with the GHG and VOC standards for fugitive emissions

components affected facilities as required by §60.5397b, you must comply

with §60.5410b(k)(1) through (5).

[40 CFR 60.5410b(k)]

1.1.5.1.1. You must develop a fugitive emissions monitoring plan as

required in §60.5397b(b), (c), and (d).

[40 CFR 60.5410b(k)(1)]

1.1.5.1.2. You must conduct an initial monitoring survey as required in

§60.5397b(e) and (f).

[40 CFR 60.5410b(k)(2)]

1.1.5.1.3. You must repair each identified source of fugitive emissions

for each affected facility as required in §60.5397b(h).

[40 CFR 60.5410b(k)(3)]

1.1.5.1.4. You must repair each identified source of fugitive emissions

for each affected facility as required in §60.5397b(h).

[40 CFR 60.5410b(k)(4)]

1.1.5.1.5. You must maintain the records specified in §60.5420b(c)(14).

[40 CFR 60.5410b(k)(5)]

1.1.6. Continuous Compliance with the Standards for the Collection of Fugitive

Emissions Components at a Compressor Station.

1.1.6.1.

Continuous compliance. For each fugitive emissions components

affected facility, you must demonstrate continuous compliance with the

requirements of §60.5397b(a) according to §60.5415b(l)(1) through (4).

[40 CFR 60.5415b(l)]

1.1.6.1.1. Monitoring. You must conduct periodic monitoring surveys as

required in §60.5397b(e) and (g).

[40 CFR 60.5415b(l)(1)]

1.1.6.1.2. Repairs. You must repair each identified source of fugitive

emissions as required in §60.5397b(h).

[40 CFR 60.5415b(l)(2)]

1.1.6.1.3. Reports. You must submit annual reports for fugitive

emissions components affected facilities as required in

§60.5420b(b)(1) and (9).

[40 CFR 60.5415b(l)(3)]

1.1.6.1.4. Records. You must maintain records as specified in

§60.5420b(c)(14).

[40 CFR 60.5415b(l)(4)]

1.1.7. Notification, Reporting, and Recordkeeping Requirements.

1.1.7.1.

Notifications. You must submit notifications according to

§60.5420b(a)(1) if you own or operate one or more of the affected

facilities specified in §60.5365b that was constructed, modified, or

reconstructed during the reporting period.

[40 CFR 60.5420b(a)]

1.1.7.1.1. If you own or operate a collection of fugitive emissions

components at a compressor station affected facility, you are

not required to submit the notifications required in

§§60.7(a)(1), (3), and (4) and 60.15(d).

[40 CFR 60.5420b(a)(1)]

1.1.7.2.

Reporting requirements. You must submit annual reports containing the

information specified in §60.5420b(b)(1), (9), and (14) following the

procedure specified in §60.5420b(b)(15). The initial annual report is due

no later than 90 days after the end of the initial compliance period as

determined according to §60.5410b. Subsequent annual reports are due no

later than the same date each year as the initial annual report. If you own

or operate more than one affected facility, you may submit one report for

multiple affected facilities provided the report contains all of the

information required as specified in §60.5420b(b)(1), (9), and (14).

Annual reports may coincide with title V reports as long as all the required

elements of the annual report are included. You may arrange with the

Administrator a common schedule on which reports required by this part

may be submitted as long as the schedule does not extend the reporting

period.

[40 CFR 60.5420b(b)]

1.1.7.2.1. The general information specified in §60.5420b(b)(1)(i)

through (iv) is required for all reports.

[40 CFR 60.5420b(b)(1)]

1.1.7.2.1.1. The company name, facility site name associated with the

affected facility, and address of the affected facility. If an

address is not available for the site, include a description

of the site location and provide the latitude and longitude

coordinates of the site in decimal degrees to an accuracy

and precision of five (5) decimals of a degree using the

North American Datum of 1983.

[40 CFR 60.5420b(b)(1)(i)]

1.1.7.2.1.2. An identification of each affected facility being included

in the annual report.

[40 CFR 60.5420b(b)(1)(ii)]

1.1.7.2.1.3. Beginning and ending dates of the reporting period.

[40 CFR 60.5420b(b)(1)(iii)]

1.1.7.2.1.4. A certification by a certifying official of truth, accuracy,

and completeness. This certification shall state that, based

on information and belief formed after reasonable

inquiry, the statements and information in the document

are true, accurate, and complete. If your report is

submitted via CEDRI, the certifier's electronic signature

during the submission process replaces the requirement in

this paragraph.

[40 CFR 60.5420b(b)(1)(iv)]

1.1.7.2.2. For the fugitive emissions components affected facility, report

the information specified in §60.5420b(b)(9)(i) and (ii), as

applicable.

[40 CFR 60.5420b(b)(9)]

1.1.7.2.2.1.1. Designation of the type of site (i.e., well site,

centralized production facility, or compressor

station) at which the fugitive emissions

components affected facility is located.

[40 CFR 60.5420b(b)(9)(i)(A)]

1.1.7.2.2.1.2. For the fugitive emissions components affected

facility at a compressor station that became an

affected facility during the reporting period, you

must include the date of startup or the date of

modification.

[40 CFR 60.5420b(b)(9)(i)(B)]

1.1.7.2.2.2. For each fugitive emissions monitoring survey performed

during the annual reporting period, the information

specified in §60.5420b(b)(9)(ii)(A) through (G).

[40 CFR 60.5420b(b)(9)(ii)]

1.1.7.2.2.2.1. Date of the survey.

[40 CFR 60.5420b(b)(9)(ii)(A)]

1.1.7.2.2.2.2. Monitoring instrument or, if the survey was

conducted by AVO methods, notation that AVO

was used.

[40 CFR 60.5420b(b)(9)(ii)(B)]

1.1.7.2.2.2.3. Any deviations from the monitoring plan

elements under §60.5397b(c)(1), (2), and (7),

(c)(8)(i), or (d) or a statement that there were no

deviations from these elements of the

monitoring plan.

[40 CFR 60.5420b(b)(9)(ii)(C)]

1.1.7.2.2.2.4. Number and type of components for which

fugitive emissions were detected.

[40 CFR 60.5420b(b)(9)(ii)(D)]

1.1.7.2.2.2.5. Number and type of fugitive emissions

components that were not repaired as required

in §60.5397b(h).

[40 CFR 60.5420b(b)(9)(ii)(E)]

1.1.7.2.2.2.6. Number and type of fugitive emission

components (including designation as difficultto-monitor or unsafe-to-monitor, if applicable)

on delay of repair and explanation for each

delay of repair.

[40 CFR 60.5420b(b)(9)(ii)(F)]

1.1.7.2.2.2.7. Date of planned shutdown(s) that occurred

during the reporting period if there are any

components that have been placed on delay of

repair.

[40 CFR 60.5420b(b)(9)(ii)(G)]

1.1.7.2.3. If you had a super-emitter event during the reporting period,

the start date of the super-emitter event, the duration of the

super-emitter event in hours, and the affected facility

associated with the super-emitter event, if applicable.

[40 CFR 60.5420b(b)(14)]

1.1.7.2.4. You must submit your annual report using the appropriate

electronic report template on the Compliance and Emissions

Data Reporting Interface (CEDRI) website for this subpart and

following the procedure specified in §60.5420b(d). If the

reporting form specific to this subpart is not available on the

CEDRI website at the time that the report is due, you must

submit the report to the Administrator at the appropriate

address listed in §60.4. Once the form has been available on

the CEDRI website for at least 90 calendar days, you must

begin submitting all subsequent reports via CEDRI. The date

reporting forms become available will be listed on the CEDRI

website. Unless the Administrator or delegated state agency or

other authority has approved a different schedule for

submission of reports, the report must be submitted by the

deadline specified in this subpart, regardless of the method in

which the report is submitted.

[40 CFR 60.5420b(b)(15)]

1.1.7.3.

Recordkeeping requirements. You must maintain the records identified

as specified in §60.7(f) and in §60.5420b(c)(14). All records required by

this subpart must be maintained either onsite or at the nearest local field

office for at least 5 years. Any records required to be maintained by this

subpart that are submitted electronically via the EPA's CEDRI may be

maintained in electronic format. This ability to maintain electronic copies

does not affect the requirement for facilities to make records, data, and

reports available upon request to a delegated air agency or the EPA as part

of an on-site compliance evaluation.

[40 CFR 60.5420b(c)]

1.1.7.3.1. For the fugitive emissions components affected facility,

maintain the records identified in §60.5420b(c)(14)(i), (iv), and

(v).

[40 CFR 60.5420b(c)(14)]

1.1.7.3.1.1. The date of startup or the date of modification for the

fugitive emissions components affected facility at a

compressor station.

[40 CFR 60.5420b(c)(14)(i)]

1.1.7.3.1.2. The fugitive emissions monitoring plan as required in

§60.5397b(b), (c), and (d).

[40 CFR 60.5420b(c)(14)(iv)]

1.1.7.3.1.3. The records of each monitoring survey as specified in

§60.5420b(c)(14)(v)(A) through (I).

[40 CFR 60.5420b(c)(14)(v)]

1.1.7.3.1.3.1. Date of the survey.

[40 CFR 60.5420b(c)(14)(v)(A)]

1.1.7.3.1.3.2. Beginning and end time of the survey.

[40 CFR 60.5420b(c)(14)(v)(B)]

1.1.7.3.1.3.3. Name of operator(s), training, and experience of

the operator(s) performing the survey.

[40 CFR 60.5420b(c)(14)(v)(C)]

1.1.7.3.1.3.4. Monitoring instrument or method used.

[40 CFR 60.5420b(c)(14)(v)(D)]

1.1.7.3.1.3.5. Fugitive emissions component identification

when Method 21 of appendix A-7 to this part is

used to perform the monitoring survey.

[40 CFR 60.5420b(c)(14)(v)(E)]

1.1.7.3.1.3.6. Ambient temperature, sky conditions, and

maximum wind speed at the time of the survey.

For compressor stations, operating mode of each

compressor (i.e., operating, standby pressurized,

and not operating-depressurized modes) at the

station at the time of the survey.

[40 CFR 60.5420b(c)(14)(v)(F)]

1.1.7.3.1.3.7. Any deviations from the monitoring plan or a

statement that there were no deviations from the

monitoring plan.

[40 CFR 60.5420b(c)(14)(v)(G)]

1.1.7.3.1.3.8. Records of calibrations for the instrument used

during the monitoring survey.

[40 CFR 60.5420b(c)(14)(v)(H)]

1.1.7.3.1.3.9. Documentation of each fugitive emission

detected during the monitoring survey,

including the information specified in

§60.5420b(c)(14)(v)(I)(1) through (9).

[40 CFR 60.5420b(c)(14)(v)(I)]

1.1.7.3.1.3.9.1. Location of each fugitive emission

identified.

[40 CFR 60.5420b(c)(14)(v)(I)(1)]

1.1.7.3.1.3.9.2. Type of fugitive emissions component,

including designation as difficult-tomonitor or unsafe-to-monitor, if

applicable.

[40 CFR 60.5420b(c)(14)(v)(I)(2)]

1.1.7.3.1.3.9.3. If Method 21 of appendix A-7 to this part

is used for detection, record the

component ID and instrument reading.

[40 CFR 60.5420b(c)(14)(v)(I)(3)]

1.1.7.3.1.3.9.4. For each repair that cannot be made during

the monitoring survey when the fugitive

emissions are initially found, a digital

photograph or video must be taken of that

component or the component must be

tagged for identification purposes. The

digital photograph must include the date

that the photograph was taken and must

clearly identify the component by location

within the site (e.g., the latitude and

longitude of the component or by other

descriptive landmarks visible in the

picture). The digital photograph or

identification (e.g., tag) may be removed

after the repair is completed, including

verification of repair with the resurvey.

[40 CFR 60.5420b(c)(14)(v)(I)(4)]

1.1.7.3.1.3.9.5. The date of first attempt at repair of the

fugitive emissions component(s).

[40 CFR 60.5420b(c)(14)(v)(I)(5)]

1.1.7.3.1.3.9.6. The date of successful repair of the

fugitive emissions component, including

the resurvey to verify repair and

instrument used for the resurvey.

[40 CFR 60.5420b(c)(14)(v)(I)(6)]

1.1.7.3.1.3.9.7. Identification of each fugitive emission

component placed on delay of repair and

explanation for each delay of repair.

[40 CFR 60.5420b(c)(14)(v)(I)(7)]

1.1.7.3.1.3.9.8. For each fugitive emission component

placed on delay of repair for reason of

replacement component unavailability, the

operator must document: the date the

component was added to the delay of

repair list, the date the replacement

fugitive component or part thereof was

ordered, the anticipated component

delivery date (including any estimated

shipment or delivery date provided by the

vendor), and the actual arrival date of the

component.

[40 CFR 60.5420b(c)(14)(v)(I)(8)]

1.1.7.3.1.3.9.9. Date of planned shutdowns that occur

while there are any components that have

been placed on delay of repair.

[40 CFR 60.5420b(c)(14)(v)(I)(9)]

1.1.7.4.

Electronic reporting. If you are required to submit notifications or

reports following the procedure specified in this paragraph, you must

submit notifications or reports to the EPA via CEDRI, which can be

accessed through the EPA's Central Data Exchange (CDX)

(https://cdx.epa.gov/). The EPA will make all the information submitted

through CEDRI available to the public without further notice to you. Do

not use CEDRI to submit information you claim as CBI. Although we do

not expect persons to assert a claim of CBI, if you wish to assert a CBI

claim for some of the information in the report or notification, you must

submit a complete file in the format specified in this subpart, including

information claimed to be CBI, to the EPA following the procedures in

§60.5420b(d). Clearly mark the part or all of the information that you

claim to be CBI. Information not marked as CBI may be authorized for

public release without prior notice. Information marked as CBI will not be

disclosed except in accordance with procedures set forth in 40 CFR part 2.

All CBI claims must be asserted at the time of submission. Anything

submitted using CEDRI cannot later be claimed CBI. Furthermore, under

CAA section 114(c), emissions data is not entitled to confidential

treatment, and the EPA is required to make emissions data available to the

public. Thus, emissions data will not be protected as CBI and will be made

publicly available. You must submit the same file submitted to the CBI

office with the CBI omitted to the EPA via the EPA's CDX as described

earlier in this paragraph.

[40 CFR 60.5420b(d)]

1.1.7.5.

Claims of EPA system outage. If you are required to electronically

submit a notification or report through CEDRI in the EPA's CDX, you

may assert a claim of EPA system outage for failure to timely comply with

that requirement. To assert a claim of EPA system outage, you must meet

the requirements outlined in paragraphs §60.5420b(e)(1) through (7).

[40 CFR 60.5420b(e)]

1.1.7.5.1. You must have been or will be precluded from accessing

CEDRI and submitting a required report within the time

prescribed due to an outage of either the EPA’s CEDRI or

CDX systems.

[40 CFR 60.5420b(e)(1)]

1.1.7.5.2. The outage must have occurred within the period of time

beginning five business days prior to the date that the

submission is due.

[40 CFR 60.5420b(e)(2)]

1.1.7.5.3. The outage may be planned or unplanned.

[40 CFR 60.5420b(e)(3)]

1.1.7.5.4. You must submit notification to the Administrator in writing as

soon as possible following the date you first knew, or through

due diligence should have known, that the event may cause or

has caused a delay in reporting.

[40 CFR 60.5420b(e)(4)]

1.1.7.5.5. You must provide to the Administrator a written description

identifying:

[40 CFR 60.5420b(e)(5)]

1.1.7.5.5.1. The date(s) and time(s) when CDX or CEDRI was

accessed and the system was unavailable;

[40 CFR 60.5420b(e)(5)(i)]

1.1.7.5.5.2. A rationale for attributing the delay in reporting beyond

the regulatory deadline to EPA system outage;

[40 CFR 60.5420b(e)(5)(ii)]

1.1.7.5.5.3. A description of measures taken or to be taken to

minimize the delay in reporting; and

[40 CFR 60.5420b(e)(5)(iii)]

1.1.7.5.5.4. The date by which you propose to report, or if you have

already met the reporting requirement at the time of the

notification, the date you reported.

[40 CFR 60.5420b(e)(5)(iv)]

1.1.7.5.6. The decision to accept the claim of EPA system outage and

allow an extension to the reporting deadline is solely within the

discretion of the Administrator.

[40 CFR 60.5420b(e)(6)]

1.1.7.5.7. In any circumstance, the report must be submitted

electronically as soon as possible after the outage is resolved.

[40 CFR 60.5420b(e)(7)]

1.1.7.6.

Claims of force majeure. If you are required to electronically submit a

report or notification through CEDRI in the EPA's CDX, you may assert a

claim of force majeure for failure to timely comply with that requirement.

To assert a claim of force majeure, you must meet the requirements

outlined in paragraphs §60.5420b(f)(1) through (5).

[40 CFR 60.5420b(f)]

1.1.7.6.1. You may submit a claim if a force majeure event is about to

occur, occurs, or has occurred or there are lingering effects

from such an event within the period of time beginning five

business days prior to the date the submission is due. For the

purposes of this section, a force majeure event is defined as an

event that will be or has been caused by circumstances beyond

the control of the affected facility, its contractors, or any entity

controlled by the affected facility that prevents you from

complying with the requirement to submit a report

electronically within the time period prescribed. Examples of

such events are acts of nature (e.g., hurricanes, earthquakes, or

floods), acts of war or terrorism, or equipment failure or safety

hazard beyond the control of the affected facility (e.g., large

scale power outage).

[40 CFR 60.5420b(f)(1)]

1.1.7.6.2. You must submit notification to the Administrator in writing as

soon as possible following the date you first knew, or through

due diligence should have known, that the event may cause or

has caused a delay in reporting.

[40 CFR 60.5420b(f)(2)]

1.1.7.6.3. You must provide to the Administrator:

[40 CFR 60.5420b(f)(3)]

1.1.7.6.3.1. A written description of the force majeure event;

[40 CFR 60.5420b(f)(3)(i)]

1.1.7.6.3.2. A rationale for attributing the delay in reporting beyond

the regulatory deadline to the force majeure event;

[40 CFR 60.5420b(f)(3)(ii)]

1.1.7.6.3.3. A description of measures taken or to be taken to

minimize the delay in reporting; and

[40 CFR 60.5420b(f)(3)(iii)]

1.1.7.6.3.4. The date by which you propose to report, or if you have

already met the reporting requirement at the time of the

notification, the date you reported.

[40 CFR 60.5420b(f)(3)(iv)]

1.1.7.6.3.5. The decision to accept the claim of force majeure and

allow an extension to the reporting deadline is solely

within the discretion of the Administrator.

[40 CFR 60.5420b(f)(4)]

1.1.7.6.3.6. In any circumstance, the reporting must occur as soon as

possible after the force majeure event occurs.

[40 CFR 60.5420b(f)(5)]

1.1.7.7.

General Provisions

Table 5 to this subpart shows which parts of the General Provisions in

§§60.1 through 60.19 apply to you.

[40 CFR 60.5425b]

Table 5 to Subpart OOOOb of Part 60 - Applicability of General Provisions to Subpart OOOOb

General

Applies to

provisions Subject of citation

Explanation

subpart?

citation

General applicability

§60.1

of the General

Yes

Provisions

§60.2

Definitions

Yes

Additional terms defined in §60.5430b.

Units and

§60.3

Yes

abbreviations

§60.4

Address

Yes

Determination of

§60.5

construction or

Yes

modification

§60.6

Review of plans

Yes

§60.7

§60.8

§60.9

§60.10

§60.11

§60.12

§60.13

Notification and

record keeping

Performance tests

Availability of

information

State authority

Compliance with

standards and

maintenance

requirements

Circumvention

Monitoring

requirements

Yes

Except that §60.7 only applies as specified in §§60.5417b(c) and

60.5420b(a).

Yes

Except that the format and submittal of performance test reports is

described in §60.5420b(b) and (d). Performance testing is required

for control devices used on storage vessels, centrifugal compressors,

and pneumatic pumps, except that performance testing is not

required for a control device used solely on pneumatic pump(s).

Yes

§60.14

Modification

Yes

§60.15

Reconstruction

Yes

§60.16

Priority list

Incorporations by

reference

General control

device and work

practice requirements

General notification

and reporting

requirement

Yes

§60.17

§60.18

§60.19

Requirements are specified in subpart OOOOb.

To the extent any provision in §60.14 conflicts with specific

provisions in subpart OOOOb, it is superseded by subpart OOOOb

provisions.

Except that §60.15(d) does not apply to wells (i.e., well

completions, well liquids unloading, associated gas wells), process

controllers, pumps, centrifugal compressors, reciprocating

compressors, storage vessels, or fugitive emissions components

affected facilities.

Yes

National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR

Part 63

2.1. 40 CFR Part 63, Subpart HH – National Emission Standards for Hazardous Air

Pollutants From Oil and Natural Gas Production Facilities [40 CFR 63.760 –

63.779, RAC 4-103]

[If applying the use of ProMax® (ProMax), Red Cedar should continue to adhere to the Subpart HH

language as written in their current permits with the exception that ProMax Version 5.0 or higher may

be used in place of GRI-GLYCalc for the specific provisions identified in the EPA approval memo. The

use of ProMax is an alternative EPA approved method (ALT-147). Should Red Cedar elect to use

ProMax as an alternative method, Red Cedar may not use another method until receiving AQD

approval.]

This facility is subject to the requirements of 40 CFR Part 63, Subpart HH for large

dehydrator(s) located at an area source of hazardous air pollutants (HAPs).

Notwithstanding conditions in this permit, the permittee shall comply with all

applicable requirements of 40 CFR Part 63, subparts A and HH.

2.1.1. General Standards

2.1.1.1.

Table 2 of this subpart specifies the provisions of subpart A (General

Provisions) of this part that apply and those that do not apply to owners

and operators of affected sources subject to this subpart.

[40 CFR 63.764(a)]

Table 2 to Subpart HH of Part 63 – Applicability of 40 CFR Part 63 General Provisions to Subpart HH

General provisions

Applicable to

reference

subpart HH

§63.1(a)(1)

Yes.

§63.1(a)(2)

Yes.

§63.1(a)(3)

Yes.

§63.1(a)(4)

Yes.

§63.1(a)(5)

§63.1(a)(6)

Yes.

§63.1(a)(7) through (a)(9)

§63.1(a)(10)

Yes.

§63.1(a)(11)

Yes.

§63.1(a)(12)

Yes.

§63.1(b)(1)

§63.1(b)(2)

§63.1(b)(3)

Yes.

§63.1(c)(1)

§63.1(c)(2)

Yes

§63.1(c)(3) and (c)(4)

§63.1(c)(5)

§63.1(d)

§63.1(e)

Yes.

§63.2

Yes

§63.3(a) through (c)

§63.4(a)(1) through (a)(2)

§63.4(a)(3) through (a)(5)

§63.4(b)

§63.4(c)

§63.5(a)(1)

§63.5(a)(2)

§63.5(b)(1)

Yes.

Explanation

Section reserved.

Subpart HH specifies applicability.

Section reserved.

Subpart HH specifies applicability.

Subpart HH exempts area sources from the requirement to obtain a Title

V permit unless otherwise required by law as specified in §63.760(h).

Section reserved.

Except definition of major source is unique for this source category and

there are additional definitions in subpart HH.

Section reserved.

§63.5(b)(2)

§63.5(b)(3)

§63.5(b)(4)

§63.5(b)(5)

§63.5(b)(6)

§63.5(c)

§63.5(d)(1)

§63.5(d)(2)

§63.5(d)(3)

§63.5(d)(4)

§63.5(e)

§63.5(f)(1)

§63.5(f)(2)

§63.6(a)

§63.6(b)(1)

§63.6(b)(2)

§63.6(b)(3)

§63.6(b)(4)

§63.6(b)(5)

§63.6(b)(6)

§63.6(b)(7)

§63.6(c)(1)

§63.6(c)(2)

§63.6(c)(3) through (c)(4)

§63.6(c)(5)

§63.6(d)

§63.6(e)(1)(i)

§63.6(e)(1)(ii)

§63.6(e)(1)(iii)

§63.6(e)(2)

§63.6(e)(3)

§63.6(f)(1)

§63.6(f)(2)

§63.6(f)(3)

§63.6(g)

§63.6(h)(1)

§63.6(h)(2) through (h)(9)

§63.6(i)(1) through (i)(14)

§63.6(i)(15)

§63.6(i)(16)

§63.6(j)

§63.7(a)(1)

Yes.

No.

Yes.

No.

Yes.

No.

Yes.

§63.7(a)(2)

Yes

§63.7(a)(3)

§63.7(a)(4)

Yes.

Section reserved.

Section Reserved.

Section reserved.

See §63.764(j) for general duty requirement.

Section reserved.

But the performance test results must be submitted within 180 days after

the compliance date.

§63.7(c)

§63.7(d)

§63.7(e)(1)

§63.7(e)(2)

§63.7(e)(3)

§63.7(e)(4)

§63.7(f)

§63.7(g)

§63.7(h)

§63.8(a)(1)

§63.8(a)(2)

§63.8(a)(3)

§63.8(a)(4)

§63.8(b)(1)

§63.8(b)(2)

§63.8(b)(3)

§63.8(c)(1)

§63.8(c)(1)(i)

§63.8(c)(1)(ii)

§63.8(c)(1)(iii)

§63.8(c)(2)

§63.8(c)(3)

§63.8(c)(4)

§63.8(c)(4)(i)

§63.8(c)(4)(ii)

§63.8(c)(5) through (c)(8)

§63.8(d)(1)

§63.8(d)(2)

Yes.

No.

Yes.

No.

Yes.

No.

Yes.

§63.8(d)(3)

Yes

§63.8(e)

Yes

§63.8(f)(1) through (f)(5)

§63.8(f)(6)

Yes.

§63.8(g)

§63.9(a)

§63.9(b)(1)

Yes.

§63.9(b)(2)

Yes

§63.9(b)(3)

§63.9(b)(4)

§63.9(b)(5)

§63.9(c)

§63.9(d)

Yes.

Section reserved.

Subpart HH does not require continuous opacity monitors.

Except for last sentence, which refers to an SSM plan. SSM plans are

not required.

Subpart HH does not specifically require continuous emissions monitor

performance evaluation, however, the Administrator can request that

one be conducted.

Subpart HH specifies continuous monitoring system data reduction

requirements.

Existing sources are given 1 year (rather than 120 days) to submit this

notification. Major and area sources that meet §63.764(e) do not have to

submit initial notifications.

Section reserved.

§63.9(e)

§63.9(f)

§63.9(g)

Yes.

§63.9(h)(1) through (h)(3)

Yes

§63.9(h)(4)

§63.9(h)(5) through (h)(6)

§63.9(i)

§63.9(j)

§63.10(a)

Yes.

§63.10(b)(1)

Yes

§63.10(b)(2)

§63.10(b)(2)(i)

Yes.

No.

§63.10(b)(2)(ii)

§63.10(b)(2)(iii)

§63.10(b)(2)(iv) through

(b)(2)(v)

§63.10(b)(2)(vi) through

(b)(2)(xiv)

Yes.

§63.10(b)(3)

Yes

§63.10(c)(1)

§63.10(c)(2) through (c)(4)

§63.10(c)(5) through (c)(8)

§63.10(c)(9)

§63.10(c)(10) through (11)

§63.10(c)(12) through (14)

§63.10(c)(15)

§63.10(d)(1)

Yes.

No.

Yes.

Section reserved.

See §63.774(g) for recordkeeping of malfunctions.

§63.10(d)(2)

Yes

Area sources located outside UA plus offset and UC boundaries do not

have to submit performance test reports.

§63.10(d)(3)

§63.10(d)(4)

§63.10(d)(5)

Yes.

§63.10(e)(1)

Yes

§63.10(e)(2)

Yes

§63.10(e)(3)(i)

Yes

§63.10(e)(3)(i)(A)

§63.10(e)(3)(i)(B)

§63.10(e)(3)(i)(C)

§63.10(e)(3)(i)(D)

Yes.

No.

Yes

Area sources located outside UA plus offset and UC boundaries are not

required to submit notifications of compliance status.

Section reserved.

§63.774(b)(1) requires sources to maintain the most recent 12 months of

data on-site and allows offsite storage for the remaining 4 years of data.

See §63.774(g) for recordkeeping of (1) occurrence and duration and (2)

actions taken during malfunctions.

No.

Yes.

§63.774(b)(1) requires sources to maintain the most recent 12 months of

data on-site and allows offsite storage for the remaining 4 years of data.

Sections reserved.

See §63.775(b)(6) or (c)(6) for reporting of malfunctions.

Area sources located outside UA plus offset and UC boundaries are not

required to submit reports.

Area sources located outside UA plus offset and UC boundaries are not

required to submit reports.

Subpart HH requires major sources to submit Periodic Reports semiannually. Area sources are required to submit Periodic Reports annually.

Area sources located outside UA plus offset and UC boundaries are not

required to submit reports.

Section reserved.

§63.10(e)(3)(ii) through

(viii)

§63.10(e)(4)

§63.10(f)

§63.11(a) and (b)

§63.11(c), (d), and (e)

§63.12(a) through (c)

§63.13(a) through (c)

§63.14(a) through (q)

§63.15(a) and (b)

§63.16

2.1.1.2.

Yes.

All reports required under this subpart shall be sent to the Tribe at the

address below. Reports may be submitted on electronic media.

[40 CFR 63.764(b)]

by email at: airquality@southernute-nsn.gov

or by United States Postal Service:

Part 70 Program

Environmental Programs Department

Air Quality Division

P.O. Box 737 MS #84

Ignacio, Colorado 81137

2.1.1.3.

or by Common Carrier:

Part 70 Program

Environmental Programs Department

Air Quality Division

398 Ouray Drive

Ignacio, CO 81137

The owner or operator of an affected source located at an existing or new

area source of HAP emissions shall comply with the applicable standards

specified below.

[40 CFR 63.764(d)]

2.1.1.3.1. Each owner or operator of an area source not located in a UA

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

comply with §63.764(d)(2)(i) through (iii).

[40 CFR 63.764(d)(2)]

2.1.1.3.1.1. Determine the optimum glycol circulation rate using the

following equation.

𝑳𝑶𝑷𝑻 = 𝟏. 𝟏𝟓 ∗ 𝟑. 𝟎

𝒈𝒂𝒍 𝑻𝑬𝑮

𝑭 ∗ (𝑰 − 𝑶)

∗

𝒍𝒃 𝑯𝟐 𝑶

𝟐𝟒 𝒉𝒓/𝒅𝒂𝒚

Where:

LOPT = Optimal circulation rate, gal/hr.

F = Gas flowrate (MMSCF/D).

I = Inlet water content (lb/MMSCF).

O = Outlet water content (lb/MMSCF).

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

water ratio (gal TEG/lb H2O).

1.15 = Adjustment factor included for a margin of safety.

[40 CFR 63.764(d)(2)(i)]

2.1.1.3.1.2. Operate the TEG dehydration unit such that the actual

glycol circulation rate does not exceed the optimum

glycol circulation rate determined in accordance with

§63.764(d)(2)(i). If the TEG dehydration unit is unable to

meet the sales gas specification for moisture content

using the glycol circulation rate determined in accordance

with paragraph §63.764(d)(2)(i), the owner or operator

must calculate an alternate circulation rate using GRIGLYCalcTM, Version 3.0 or higher, or ProMax. The

owner or operator must document why the TEG

dehydration unit must be operated using the alternate

circulation rate and submit this documentation with the

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

[40 CFR 63.764(d)(2)(ii)]

2.1.1.3.1.3. Maintain a record of the determination specified in

§63.764(d)(2)(ii) in accordance with the requirements in

§63.774(f) and submit the Initial Notification in

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

operating conditions change and a modification to the

optimum glycol circulation rate is required, the owner or

operator shall prepare a new determination in accordance

with §63.764(d)(2)(i) or (ii) and submit the information

specified under §63.775(c)(7)(ii) through (v).

[40 CFR 63.764(d)(2)(iii)]

2.1.1.4.

At all times the owner or operator must operate and maintain any affected

source, including associated air pollution control equipment and

monitoring equipment, in a manner consistent with safety and good air

pollution control practices for minimizing emissions. Determination of

whether such operation and maintenance procedures are being used will be

based on information available to the Administrator which may include,

but is not limited to, monitoring results, review of operation and

maintenance procedures, review of operation and maintenance records,

and inspection of the source.

[40 CFR 63.764(j)]

2.1.2. Test Methods, Compliance Procedures, and Compliance Demonstrations

2.1.2.1.

Determination of glycol dehydration unit flowrate, benzene emissions,

or BTEX emissions. The procedures of this paragraph shall be used by an

owner or operator to determine glycol dehydration unit natural gas

flowrate, benzene emissions, or BTEX emissions.

[40 CFR 63.772(b)]

2.1.2.1.1. The determination of actual flowrate of natural gas to a glycol

dehydration unit shall be made using §63.772(b)(1)(ii).

[40 CFR 63.772(b)(1)]

2.1.2.1.1.1. The owner or operator shall document, to the

Administrator’s satisfaction, the actual annual average

natural gas flowrate to the glycol dehydration unit.

[40 CFR 63.772(b)(1)(ii)]

2.1.2.1.2. The determination of actual average benzene or BTEX

emissions from a glycol dehydration unit shall be made using

the procedures of §63.772(b)(2)(i). Emissions shall be

determined either uncontrolled, or with federally enforceable

controls in place.

[40 CFR 63.772(b)(2)]

2.1.2.1.2.1. The owner or operator shall determine actual average

benzene or BTEX emissions using an approved model

(GRI-GLYCalcTM, Version 3.0 or higher, or ProMax). If

GRI-GLYCalcTM is used, follow the procedures presented

in the associated GRI-GLYCalcTM Technical Reference

Manual. Inputs to the model shall be representative of

actual operating conditions of the glycol dehydration unit

and may be determined using the procedures documented

in the Gas Research Institute (GRI) report entitled

“Atmospheric Rich/Lean Method for Determining Glycol

Dehydrator Emissions” (GRI-95/0368.1).

[40 CFR 63.772(b)(2)(i)]

2.1.3. Recordkeeping Requirements

2.1.3.1.

Except as specified in §63.774(f), each owner or operator of a facility

subject to this subpart shall maintain the records specified in

§63.774(b)(1) and (2).

[40 CFR 63.774(b)]

2.1.3.1.1. The owner or operator of an affected source subject to the

provisions of this subpart shall maintain files of all information

(including all reports and notifications) required by this

subpart. The files shall be retained for at least 5 years following

the date of each occurrence, measurement, maintenance,

corrective action, report or period.

[40 CFR 63.774(b)(1)]

2.1.3.1.1.1. All applicable records shall be maintained in such a

manner that they can be readily accessed.

[40 CFR 63.774(b)(1)(i)]

2.1.3.1.1.2. The most recent 12 months of records shall be retained on

site or shall be accessible from a central location by

computer or other means that provides access within 2

hours after a request.

[40 CFR 63.774(b)(1)(ii)]

2.1.3.1.1.3. The remaining 4 years of records may be retained offsite.

[40 CFR 63.774(b)(1)(iii)]

2.1.3.1.1.4. Records may be maintained in hard copy or computerreadable form including, but not limited to, on paper,

microfilm, computer, floppy disk, magnetic tape, or

microfiche.

[40 CFR 63.774(b)(1)(iv)]

2.1.3.1.2. Records specified in §63.10(b)(2).

[40 CFR 63.774(b)(2)]

2.1.3.2.

The owner or operator of an area source not located within a UA plus

offset and UC boundary must keep a record of the calculation used to

determine the optimum glycol circulation rate in accordance with

§63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable.

[40 CFR 63.774(f)]

2.1.3.3.

The owner or operator of an affected source subject to this subpart shall

maintain records of the occurrence and duration of each malfunction of

operation (i.e., process equipment) or the air pollution control equipment

and monitoring equipment. The owner or operator shall maintain records

of actions taken during periods of malfunction to minimize emissions in

accordance with §63.764(j), including corrective actions to restore

malfunctioning process and air pollution control and monitoring

equipment to its normal or usual manner of operation.

[40 CFR 63.774(g)]

2.1.4. Reporting Requirements

2.1.4.1.

The owner or operator of an area source subject to this subpart shall

submit the information listed in §63.775(c)(1). If the source is not located

within any UA plus offset and UC boundaries, the owner or operator shall

also submit the information listed within §63.775(c)(7).

[40 CFR 63.775(c)]

2.1.4.1.1. In addition to submitting your initial notification to the

addressees specified under §63.9(a), you must also submit a

copy of the initial notification to the EPA's Office of Air

Quality Planning and Standards. Send your notification via

email to Oil and Gas Sector@epa.gov or via U.S. mail or other

mail delivery service to U.S. EPA, Sector Policies and

Programs Division/Fuels and Incineration Group (E143-01),

Attn: Oil and Gas Project Leader, Research Triangle Park, NC

27711.

[40 CFR 63.775(c)(1)]

2.1.4.1.2. The information listed in §63.775(c)(1)(i) through (v) shall be

submitted with the initial notification.

[40 CFR 63.775(c)(7)]

2.1.4.1.2.1. Documentation of the source's location relative to the

nearest UA plus offset and UC boundaries. This

information shall include the latitude and longitude of the

affected source; whether the source is located in an urban

cluster with 10,000 people or more; the distance in miles

to the nearest urbanized area boundary if the source is not

located in an urban cluster with 10,000 people or more;

and the name of the nearest urban cluster with 10,000

people or more and nearest urbanized area.

[40 CFR 63.775(c)(7)(i)]

2.1.4.1.2.2. Calculation of the optimum glycol circulation rate

determined in accordance with §63.764(d)(2)(i).

[40 CFR 63.775(c)(7)(ii)]

2.1.4.1.2.3. If applicable, documentation of the alternate glycol

circulation rate calculated using GRI-GLYCalcTM,

Version 3.0 or higher, or ProMax, and documentation

stating why the TEG dehydration unit must operate using

the alternate glycol circulation rate.

[40 CFR 63.775(c)(7)(iii)]

2.1.4.1.2.4. The name of the manufacturer and the model number of

the glycol circulation pump(s) in operation.

[40 CFR 63.775(c)(7)(iv)]

2.1.4.1.2.5. Statement by a responsible official, with that official's

name, title, and signature, certifying that the facility will

always operate the glycol dehydration unit using the

optimum circulation rate determined in accordance with

§63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable.

[40 CFR 63.775(c)(7)(v)]

2.1.4.2.

Each owner or operator of a source subject to this subpart shall submit a

Notification of Compliance Status Report as required under §63.9(h)

within 180 days after the compliance date specified in §63.760(f). In

addition to the information required under §63.9(h), the Notification of

Compliance Status Report shall include the information specified in

§63.775(d)(7), (9), and (10). This information may be submitted in an

operating permit application, in an amendment to an operating permit

application, in a separate submittal, or in any combination of the three. If

all of the information required under this paragraph has been submitted at

any time prior to 180 days after the applicable compliance dates specified

in §63.760(f), a separate Notification of Compliance Status Report is not

required. If an owner or operator submits the information specified in

§63.775(d)(7), (9), and (10) at different times, and/or different submittals,

subsequent submittals may refer to previous submittals instead of

duplicating and resubmitting the previously submitted information.

[40 CFR 63.775(d)]

2.1.4.2.1. After a title V permit has been issued to the owner or operator

of an affected source, the owner or operator of such source

shall comply with all requirements for compliance status

reports contained in the source's title V permit, including

reports required under this subpart. After a title V permit has

been issued to the owner or operator of an affected source, and

each time a notification of compliance status is required under

this subpart, the owner or operator of such source shall submit

the notification of compliance status to the appropriate

permitting authority following completion of the relevant

compliance demonstration activity specified in this subpart.

[40 CFR 63.775(d)(7)]

2.1.4.2.2. The owner or operator shall submit the analysis performed

under §63.760(a)(1).

[40 CFR 63.775(d)(9)]

2.1.4.2.3. The owner or operator shall submit a statement as to whether

the source has complied with the requirements of this subpart.

[40 CFR 63.775(d)(10)]

2.1.4.3.

Notification of process change. Whenever a process change is made, or a

change in any of the information submitted in the Notification of

Compliance Status Report, the owner or operator shall submit a report

within 180 days after the process change is made. The report shall include:

[40 CFR 63.775(f)]

2.1.4.3.1. A brief description of the process change;

[40 CFR 63.775(f)(1)]

2.1.4.3.2. A description of any modification to standard procedures or

quality assurance procedures;

[40 CFR 63.775(f)(2)]

2.1.4.3.3. Revisions to any of the information reported in the original

Notification of Compliance Status Report under §63.775(d);

and

[40 CFR 63.775(f)(3)]

2.1.4.3.4. Information required by the Notification of Compliance Status

Report under §63.775(d) for changes involving the addition of

processes or equipment.

[40 CFR 63.775(f)(4)]

2.2. 40 CFR Part 63, Subpart ZZZZ – National Emission Standards for Hazardous

Air Pollutants From Oil and Natural Gas Production Facilities [40 CFR 63.6580 –

63.6675, RAC 4-103]

This facility is subject to the requirements of 40 CFR Part 63, Subpart ZZZZ for new

stationary reciprocating internal combustion engines (RICE) with a site rating of more

than 500 brake horsepower located at a major source of HAP emission. Notwithstanding

conditions in this permit, the permittee shall comply with all applicable requirements of

40 CFR Part 63 subparts A and ZZZZ.

2.2.1. Affected Sources

The following emission unit is considered an affected source under 40 CFR Part

63, Subpart ZZZZ:

C-204 – Caterpillar G3516LE (4SLB SI) Compressor Engine, 1,208 Site Rated HP

[40 CFR 63.6585 & 63.6590]

2.2.2.

Emission and Operating Limitations

2.2.2.1.

You must comply with the requirements in Tables 2a and 2b to this

subpart which apply.

Table 2a to Subpart ZZZZ of Part 63 - Emission Limitations for New and Reconstructed 4SLB

Stationary RICE ≥ 250 HP Located at a Major Source of HAP Emissions

You must meet the

following emission

For each . . .

During periods of startup you must . . .

limitation, except during

periods of startup . . .

Minimize the engine's time spent at idle and minimize the

2. 4SLB

engine's startup time at startup to a period needed for

a. Reduce CO emissions by

stationary

appropriate and safe loading of the engine, not to exceed 30

93 percent or more

RICE

minutes, after which time the non-startup emission

limitations apply.1

Sources can petition the Administrator pursuant to the requirements of 40 CFR 63.6(g) for alternative work practices.

Table 2b to Subpart ZZZZ of Part 63—Operating Limitations for New and Reconstructed 4SLB

Stationary RICE ≥ 250 HP Located at a Major Source of HAP Emissions

You must meet the following operating limitation, except during

For each . . .

periods of startup . . .

1. New and reconstructed

a. maintain your catalyst so that the pressure drop across the catalyst does

4SLB stationary RICE ≥ 250

not change by more than 2 inches of water at 100 percent load plus or minus

HP located at a major source

10 percent from the pressure drop across the catalyst that was measured

of HAP emissions

during the initial performance test; and

complying with the

requirement to reduce CO

b. maintain the temperature of your stationary RICE exhaust so that the

emissions and using an

catalyst inlet temperature is greater than or equal to 450 °F and less than or

oxidation catalyst

equal to 1350 °F.1

Sources can petition the Administrator pursuant to the requirements of 40 CFR 63.8(f) for a different temperature

range.

[40 CFR 63.6600]

2.2.3. General Compliance Requirements

2.2.3.1.

You must be in compliance with the emission limitations, operating

limitations, and other requirements in this subpart that apply at all times.

[40 CFR 63.6605(a)]

2.2.3.2.

2.2.4.

At all times you must operate and maintain any affected source, including

associated air pollution control equipment and monitoring equipment, in a

manner consistent with safety and good air pollution control practices for

minimizing emissions. The general duty to minimize emissions does not

require the permittee to make any further efforts to reduce emissions if

levels required by this standard have been achieved. Determination of

whether such operation and maintenance procedures are being used will be

based on information available to the Tribe which may include, but is not

limited to, monitoring results, review of operation and maintenance

procedures, review of operation and maintenance records, and inspection

of the source.

[40 CFR 63.6605(b)]

Testing and Initial Compliance Requirements

2.2.4.1.

You must conduct the initial performance test or other initial compliance

demonstrations in Table 4 to this subpart that apply to you within 180 days

after the compliance date that is specified for your stationary RICE in

§63.6595 and according to the provisions in §63.7(a)(2).

[40 CFR 63.6610(a)]

Table 4 to Subpart ZZZZ of Part 63—Requirements for Performance Tests

As stated in §§63.6610, 63.6611, 63.6620, and 63.6640, you must comply with the following requirements for

performance tests for stationary RICE:

Complying with the

According to the

For each . . .

You must . . .

Using . . .

requirement to . . .

following requirements . . .

1. 4SLB

a. Reduce CO

i. Select the

(a) For CO, O2, and moisture

stationary

emissions

sampling port

measurement, ducts ≤6 inches in

RICE

location and the

diameter may be sampled at a

number/locatio

single point located at the duct

n of traverse

centroid and ducts >6 and ≤12

points at the

inches in diameter may be

inlet and outlet

sampled at 3 traverse points

of the control

located at 16.7, 50.0, and 83.3%

device; and

of the measurement line ('3point long line'). If the duct is

>12 inches in diameter and the

sampling port location meets the

two and half-diameter criterion

of section 11.1.1 of method 1 of

40 CFR part 60, appendix A-1,

the duct may be sampled at `3point long line'; otherwise,

conduct the stratification testing

and select sampling points

according to section 8.1.2 of

method 7E of 40 CFR part 60,

appendix A-4.

ii. Measure the

O2 at the inlet

and outlet of

the control

device; and

(1) Method 3 or

3A or 3B of 40

CFR part 60,

appendix A-2,

or ASTM

D6522-00

(Reapproved

2005)13 (heated

probe not

necessary)

(b) Measurements to determine

O2 must be made at the same

time as the measurements for

CO concentration.

iii. Measure the

CO at the inlet

and the outlet

of the control

device

(2) ASTM

D6522-00

(Reapproved

2005)123 heated

probe not

necessary) or

method 10 of

40 CFR part 60,

appendix A-4

be at 15 percent O2, dry basis.

iv. Measure

(3) Method 4 of

moisture

40 CFR part 60,

content at the

appendix A-3,

inlet and outlet

or method 320

of the control

of 40 CFR part

device as

63, appendix A,

needed to

or ASTM

determine CO

D6348-0313

and O2

concentrations

on a dry basis

You may also use methods 3A and 10 as options to ASTM-D6522-00 (2005).

(d) Measurements to determine

moisture content must be made

at the same time and location as

the measurements for CO

concentration.

You may obtain a copy of ASTM-D6348-03 from at least one of the following addresses: American Society for

Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms

International, 300 North Zeeb Road, Ann Arbor, MI 48106.

Incorporated by reference, see §63.14.

2.2.4.2.

An owner or operator is not required to conduct an initial performance test

on units for which a performance test has been previously conducted, but

the test must meet all of the conditions described in §63.6610(d)(1)

through (5).

[40 CFR 63.6610(d)]

2.2.4.2.1. The test must have been conducted using the same methods

specified in this subpart, and these methods must have been

followed correctly.

[40 CFR 63.6610(d)(1)]

2.2.4.2.2. The test must not be older than 2 years.

[40 CFR 63.6610(d)(2)]

2.2.4.2.3. The test must be reviewed and accepted by the Administrator.

[40 CFR 63.6610(d)(3)]

2.2.4.2.4. Either no process or equipment changes must have been made

since the test was performed, or the owner or operator must be

able to demonstrate that the results of the performance test,

with or without adjustments, reliably demonstrate compliance

despite process or equipment changes.

[40 CFR 63.6610(d)(4)]

2.2.4.2.5. The test must be conducted at any load condition within plus or

minus 10 percent of 100 percent load.

[40 CFR 63.6610(d)(5)]

2.2.4.3.

You must conduct subsequent performance tests as specified in Table 3 of

this subpart.

[40 CFR 63.6615]

2.2.4.3.1. For semiannual performance tests, the tests shall be performed

each consecutive calendar half-year. A calendar half-year is

defined as the six-month period from January 1 through June

30 or from July 1 through December 31. All semiannual

performance tests shall be performed within 8 months of the

previous test.

2.2.4.3.2. For annual performance tests, the tests shall be performed each

consecutive calendar year between January and December.

Subsequent tests shall be performed within 14 months after the

previous test.

[40 CFR 63.6615 and RAC 2-110(5)]

Table 3 to Subpart ZZZZ of Part 63—Subsequent Performance Tests

Complying with the

For each . . .

You must . . .

requirement to . . .

1. New or reconstructed 4SLB stationary

Reduce CO emissions and

Conduct subsequent

RICE ≥ 250 HP located at major sources

not using a CEMS

performance tests

semiannually.1

After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent

performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE

is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating

limitations, you must resume semiannual performance tests.

[40 CFR 63.6615]

2.2.4.4.

You must conduct each performance test in Tables 3 and 4 of this subpart

that applies to you.

[40 CFR 63.6620(a)]

2.2.4.5.

Each performance test must be conducted according to the requirements

that this subpart specifies in Table 4 to this subpart. If you own or operate

a non-operational stationary RICE that is subject to performance testing,

you do not need to start up the engine solely to conduct the performance

test. Owners and operators of a non-operational engine can conduct the

performance test when the engine is started up again. The test must be

conducted at any load condition within plus or minus 10 percent of 100

percent load for the stationary RICE.

[40 CFR 63.6620(b)]

2.2.4.6.

You must conduct three separate test runs for each performance test

required in this section, as specified in §63.7(e)(3). Each test run must last

at least 1 hour, unless otherwise specified in this subpart.

[40 CFR 63.6620(d)]

2.2.4.6.1. You must use Equation 1 of this section to determine

compliance with the percent reduction requirement:

𝑪𝒊 − 𝑪𝒐

× 𝟏𝟎𝟎 = 𝑹 (𝑬𝒒. 𝟏)

𝑪𝒊

Where:

Ci = concentration of carbon monoxide (CO), total hydrocarbons

(THC), or formaldehyde at the control device inlet,

Co = concentration of CO, THC, or formaldehyde at the control

device outlet, and

R = percent reduction of CO, THC, or formaldehyde

emissions.

[40 CFR 63.6620(e)(1)]

2.2.4.6.2. You must normalize the CO, THC, or formaldehyde

concentrations at the inlet and outlet of the control device to a

dry basis and to 15 percent oxygen, or an equivalent percent

carbon dioxide (CO2). If pollutant concentrations are to be

corrected to 15 percent oxygen and CO2 concentration is

measured in lieu of oxygen concentration measurement, a

CO2 correction factor is needed. Calculate the CO2 correction

factor as described in §63.6620(e)(2)(i) through (iii).

[40 CFR 63.6620(e)(2)]

2.2.4.6.2.1. Calculate the fuel-specific Fo value for the fuel burned

during the test using values obtained from Method 19,

Section 5.2, and the following equation:

𝑭𝒐 =

𝟎. 𝟐𝟎𝟗 𝑭𝒅

(𝑬𝒒. 𝟐)

𝑭𝒄

Where:

Fo = Fuel factor based on the ratio of oxygen volume to

the ultimate CO2 volume produced by the fuel at zero

percent excess air.

0.209 = Fraction of air that is oxygen, percent/100.

Fd = Ratio of the volume of dry effluent gas to the gross

calorific value of the fuel from Method 19, dsm 3/J

(dscf/106 Btu).

Fc = Ratio of the volume of CO2 produced to the gross

calorific value of the fuel from Method 19, dsm 3/J

(dscf/106 Btu)

[40 CFR 63.6620(e)(2)(i)]

2.2.4.6.2.2. Calculate the CO2 correction factor for correcting

measurement data to 15 percent O2, as follows:

𝑿𝑪𝑶𝟐 =

𝟓. 𝟗

(𝑬𝒒. 𝟑)

𝑭𝒐

Where:

XCO2 = CO2 correction factor, percent

5.9 = 20.9 percent O2 – 15 percent O2, the defined O2

correction value, percent

[40 CFR 63.6620(e)(2)(ii)]

2.2.4.6.2.3. Calculate the CO, THC, and formaldehyde gas

concentrations adjusted to 15 percent O2 using CO2 as

follows:

𝑪𝒂𝒅𝒋 = 𝑪𝒅

𝑿𝑪𝑶𝟐

(𝑬𝒒. 𝟒)

%𝑪𝑶𝟐

Where:

Cadj = Calculated concentration of CO, THC, or

formaldehyde adjusted to 15 percent O2.

Cd = Measured concentration of CO, THC, or

formaldehyde, uncorrected.

XCO2 = CO2 correction factor, percent.

%CO2 = Measured CO2 concentration measured, dry

basis, percent.

[40 CFR 63.6620(e)(2)(iii)]

2.2.4.7.

The engine percent load during a performance test must be determined by

documenting the calculations, assumptions, and measurement devices

used to measure or estimate the percent load in a specific application. A

written report of the average percent load determination must be included

in the notification of compliance status. The following information must

be included in the written report: the engine model number, the engine

manufacturer, the year of purchase, the manufacturer's site-rated brake

horsepower, the ambient temperature, pressure, and humidity during the

performance test, and all assumptions that were made to estimate or

calculate percent load during the performance test must be clearly

explained. If measurement devices such as flow meters, kilowatt meters,

beta analyzers, stain gauges, etc. are used, the model number of the

measurement device, and an estimate of its accurate in percentage of true

value must be provided.

[40 CFR 63.6620(i)]

2.2.4.8.

Beginning on February 26, 2025, within 60 days after the date of

completing each performance test required by this subpart, you must

submit the results of the performance test following the procedure

specified in §63.9(k). Data collected using test methods supported by the

EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT

website (https://www.epa.gov/electronic-reporting-airemissions/electronic-reporting-tool-ert) at the time of the test must be

submitted in a file format generated using the EPA's ERT. Alternatively,

you may submit an electronic file consistent with the extensible markup

language (XML) schema listed on the EPA's ERT website. Data collected

using test methods that are not supported by the EPA's ERT as listed on

the EPA's ERT website at the time of the test must be included as an

attachment in the ERT or alternate electronic file.

[40 CFR 63.6620(j)]

2.2.4.9.

If you are required to install a continuous parameter monitoring system

(CPMS) as specified in Table 5 of this subpart, you must install, operate,

and maintain each CPMS according to the requirements in §63.6625(b)(1)

through (6).

[40 CFR 63.6625(b)]

Table 5 to Subpart ZZZZ of Part 63—Initial Compliance With Emission Limitations, Operating

Limitations, and Other Requirements

As stated in §§63.6612, 63.6625 and 63.6630, you must initially comply with the emission and operating

limitations as required by the following:

Complying with the

You have demonstrated initial

For each . . .

requirement to . . .

compliance if . . .

1. New or reconstructed nona. Reduce CO

i. The average reduction of emissions

emergency 4SLB stationary RICE

emissions and using

of CO determined from the initial

≥250 HP located at a major source

oxidation catalyst, and

performance test achieves the required

of HAP

using a CPMS

CO percent reduction; and

ii. You have installed a CPMS to

continuously monitor catalyst inlet

temperature according to the

requirements in §63.6625(b); and

iii. You have recorded the catalyst

pressure drop and catalyst inlet

temperature during the initial

performance test.

2.2.4.9.1. You must prepare a site-specific monitoring plan that addresses

the monitoring system design, data collection, and the quality

assurance and quality control elements outlined in

§63.6625(b)(1)(i) through (v) and in §63.8(d). As specified in

§63.8(f)(4), you may request approval of monitoring system

quality assurance and quality control procedures alternative to

those specified in paragraphs §63.6625(b)(1) through (5) in

your site-specific monitoring plan.

[40 CFR 63.6625(b)(1)]

2.2.4.9.1.1. The performance criteria and design specifications for the

monitoring system equipment, including the sample

interface, detector signal analyzer, and data acquisition

and calculations;

[40 CFR 63.6625(b)(1)(i)]

2.2.4.9.1.2. Sampling interface (e.g., thermocouple) location such that

the monitoring system will provide representative

measurements;

[40 CFR 63.6625(b)(1)(ii)]

2.2.4.9.1.3. Equipment performance evaluations, system accuracy

audits, or other audit procedures;

[40 CFR 63.6625(b)(1)(iii)]

2.2.4.9.1.4. Ongoing operation and maintenance procedures in

accordance with provisions in §63.8(c)(1)(ii) and (c)(3);

and

[40 CFR 63.6625(b)(1)(iv)]

2.2.4.9.1.5. Ongoing reporting and recordkeeping procedures in

accordance with provisions in §63.10(c), (e)(1), and

(e)(2)(i).

[40 CFR 63.6625(b)(1)(v)]

2.2.4.9.2. You must install, operate, and maintain each CPMS in

continuous operation according to the procedures in your sitespecific monitoring plan.

[40 CFR 63.6625(b)(2)]

2.2.4.9.3. The CPMS must collect data at least once every 15 minutes

(see also §63.6635).

[40 CFR 63.6625(b)(3)]

2.2.4.9.4. For a CPMS for measuring temperature range, the temperature

sensor must have a minimum tolerance of 2.8 degrees Celsius

(5 degrees Fahrenheit) or 1 percent of the measurement range,

whichever is larger.

[40 CFR 63.6625(b)(4)]

2.2.4.9.5. You must conduct the CPMS equipment performance

evaluation, system accuracy audits, or other audit procedures

specified in your site-specific monitoring plan at least annually.

[40 CFR 63.6625(b)(5)]

2.2.4.9.6. You must conduct a performance evaluation of each CPMS in

accordance with your site-specific monitoring plan.

[40 CFR 63.6625(b)(6)]

2.2.4.10.

You must minimize the engine's time spent at idle during startup and

minimize the engine's startup time to a period needed for appropriate and

safe loading of the engine, not to exceed 30 minutes, after which time the

emission standards applicable to all times other than startup in Table 2a to

this subpart apply.

[40 CFR 63.6625(h)]

2.2.4.11.

You must demonstrate initial compliance with each emission limitation,

operating limitation, and other requirement that applies to you according

to Table 5 of this subpart.

[40 CFR 63.6630(a)]

2.2.4.12.

During the initial performance test, you must establish each operating

limitation in Table 2b of this subpart that applies to you.

[40 CFR 63.6630(b)]

2.2.4.13.

You must submit the Notification of Compliance Status containing the

results of the initial compliance demonstration according to the

requirements in §63.6645.

[40 CFR 63.6630(c)]

2.2.5.

Continuous Compliance Requirements

If you must comply with emission and operating limitations, you must monitor

and collect data according to this section.

2.2.5.1.

Except for monitor malfunctions, associated repairs, required performance

evaluations, and required quality assurance or control activities, you must

monitor continuously at all times that the stationary RICE is operating. A

monitoring malfunction is any sudden, infrequent, not reasonably

preventable failure of the monitoring to provide valid data. Monitoring

failures that are caused in part by poor maintenance or careless operation

are not malfunctions.

[40 CFR 63.6635(b)]

2.2.5.2.

You may not use data recorded during monitoring malfunctions,

associated repairs, and required quality assurance or control activities in

data averages and calculations used to report emission or operating levels.

You must, however, use all the valid data collected during all other

periods.

[40 CFR 63.6635(c)]

2.2.5.3.

You must demonstrate continuous compliance with each requirement in

Tables 2a and 2b to this subpart that applies to you according to methods

specified in Table 6 to this subpart.

[40 CFR 63.6640(a)]

Table 6 to Subpart ZZZZ of Part 63—Continuous Compliance With Emission Limitations, and Other

Requirements

As stated in §63.6640, you must continuously comply with the emissions and operating limitations and work or

management practices as required by the following:

Complying with the

You must demonstrate continuous compliance

For each . . .

requirement to . . .

by . . .

1. New or reconstructed nona. Reduce CO emissions

i. Conducting semiannual performance tests for

emergency 4SLB stationary

and using an oxidation

CO to demonstrate that the required CO percent

RICE ≥250 HP located at a

catalyst, and using a

reduction is achieveda; and

major source of HAP

CPMS

ii. Collecting the catalyst inlet temperature data

according to §63.6625(b); and

iii. Reducing these data to 4-hour rolling averages;

and

iv. Maintaining the 4-hour rolling averages within

the operating limitations for the catalyst inlet

temperature; and

v. Measuring the pressure drop across the catalyst

once per month and demonstrating that the

pressure drop across the catalyst is within the

operating limitation established during the

performance test.

After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent

performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE

is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating

limitations, you must resume semiannual performance tests.

2.2.5.4.

You must report each instance in which you did not meet each

requirement in Tables 2a and 2b to this subpart that applies. These

instances are deviations from the emission and operating limitations in this

subpart. These deviations must be reported according to the requirements

in §63.6650. If you change your catalyst, you must reestablish the values

of the operating parameters measured during the initial performance test.

When you reestablish the values of your operating parameters, you must

also conduct a performance test to demonstrate that you are meeting the

required emission limitation applicable to your stationary RICE.

[40 CFR 63.6640(b)]

2.2.5.4.1. You must conduct the performance test within 180 days of the

catalyst change.

[RAC 2-110(5)]

2.2.5.5.

For new, reconstructed, and rebuilt stationary RICE, deviations from the

emission or operating limitations that occur during the first 200 hours of

operation from engine startup (engine burn-in period) are not violations.

Rebuilt stationary RICE means a stationary RICE that has been rebuilt as

that term is defined in 40 CFR 94.11(a).

[40 CFR 63.6640(d)]

2.2.5.6.

You must also report each instance in which you did not meet the

requirements in Table 8 to this subpart that apply.

[40 CFR 63.6640(e)]

2.2.6.

Notifications, Reports, and Records

2.2.6.1.

You must submit all of the notifications in §§63.7(b) and (c), 63.8(e),

(f)(4), 63.9(b) through (e), and (g) and (h) that apply by the dates

specified.

[40 CFR 63.6645(a)]

2.2.6.2.

If you start up your new or reconstructed stationary RICE with a site

rating of more than 500 brake HP located at a major source of HAP

emissions on or after August 16, 2004, you must submit an Initial

Notification not later than 120 days after you become subject to this

subpart. Beginning on February 26, 2025, submit the notification

electronically in PDF consistent with §63.9(k).

[40 CFR 63.6645(c)]

2.2.6.3.

You must submit a Notification of Intent to conduct a performance test at

least 60 days before the performance test is scheduled to begin as required

in §63.7(b)(1).

[40 CFR 63.6645(g)]

2.2.6.4.

If you are required to conduct a performance test or other initial

compliance demonstration as specified in Tables 4 and 5 to this subpart,

you must submit a Notification of Compliance Status according to

§63.9(h)(2)(ii).

[40 CFR 63.6645(h)]

2.2.6.4.1. For each initial compliance demonstration required in Table 5

to this subpart that does not include a performance test, you

must submit the Notification of Compliance Status before the

close of business on the 30th day following the completion of

the initial compliance demonstration.

[40 CFR 63.6645(h)(1)]

2.2.6.4.2. For each initial compliance demonstration required in Table 5

to this subpart that includes a performance test conducted

according to the requirements in Table 3 to this subpart, you

must submit the Notification of Compliance Status, including

the performance test results, before the close of business on the

60th day following the completion of the performance test

according to §63.10(d)(2). Beginning on February 26, 2025, for

each initial compliance demonstration required in table 5 to

this subpart that includes a performance test conducted

according to the requirements in table 3 to this subpart, you

must submit the Notification of Compliance Status, including a

summary of the performance test results, in PDF to the EPA

via the Compliance and Emissions Data Reporting Interface

(CEDRI), before the close of business on the 60th day

following the completion of the performance test following the

procedure specified in §63.9(k), except any Confidential

Business Information (CBI) is to be submitted according to

§63.6645(h)(2)(i) and (ii). Do not use CEDRI to submit

information you claim as CBI. Although we do not expect

persons to assert a claim of CBI, if you wish to assert a CBI

claim for some of the information in the report, you must

submit a complete file, including information claimed to be

CBI, to the EPA following the procedures in §63.6645(h)(2)(i)

and (ii). Clearly mark the part or all of the information that you

claim to be CBI. Information not marked as CBI may be

authorized for public release without prior notice. Information

marked as CBI will not be disclosed except in accordance with

procedures set forth in 40 CFR part 2. All CBI claims must be

asserted at the time of submission. Anything submitted using

CEDRI cannot later be claimed CBI. Furthermore, under CAA

section 114(c), emissions data is not entitled to confidential

treatment, and the EPA is required to make emissions data

available to the public. Thus, emissions data will not be

protected as CBI and will be made publicly available. You

must submit the same file submitted to the CBI office with the

CBI omitted to the EPA via the EPA's CDX as described

earlier in §63.6645(h)(2).

[40 CFR 63.6645(h)(2)]

2.2.6.4.2.1. The preferred method to receive CBI is for it to be

transmitted electronically using email attachments, File

Transfer Protocol, or other online file sharing services.

Electronic submissions must be transmitted directly to the

OAQPS CBI Office at the email address

oaqpscbi@epa.gov, and as described in §63.6645(h)(2),

should include clear CBI markings and be flagged to the

attention of the Reciprocating Internal Combustion

Engine Sector Lead. If assistance is needed with

submitting large electronic files that exceed the file size

limit for email attachments, and if you do not have your

own file sharing service, please email oaqpscbi@epa.gov

to request a file transfer link.

[40 CFR 63.6645(h)(2)(i)]

2.2.6.4.2.2. If you cannot transmit the file electronically, you may

send CBI information through the postal service to the

following address: OAQPS Document Control Officer

(C404-02), OAQPS, U.S. Environmental Protection

Agency, 109 T.W. Alexander Drive, P.O. Box 12055,

Research Triangle Park, North Carolina 27711, Attention

Reciprocating Internal Combustion Engine Sector Lead.

The mailed CBI material should be double wrapped and

clearly marked. Any CBI markings should not show

through the outer envelope.

[40 CFR 63.6645(h)(2)(ii)]

2.2.6.5.

You must submit each report in Table 7 of this subpart that applies to you.

[40 CFR 63.6650(a)]

Table 7 to Subpart ZZZZ of Part 63 - Requirements for Reports

As stated in §63.6650, you must comply with the following requirements for reports:

You must submit

The report must contain

You must submit the

For each . . .

a. . .

. . .

report . . .

1. New or reconstructed

Compliance report

a. If there are no deviations

i. Semiannually

non-emergency

from any emission

according to the

stationary RICE >500

limitations or operating

requirements in

HP located at a major

limitations that apply to you,

§63.6650(b)(1)-(5) and

source of HAP

a statement that there were no (i) for engines that are

deviations from the emission not limited use

limitations or operating

stationary RICE subject

limitations during the

to numerical emission

reporting period. If there

limitations; and

were no periods during which

the CMS, including CEMS

ii. Annually according

and CPMS, was out-ofto the requirements in

control, as specified in

§63.6650(b)(6)-(9) and

§63.8(c)(7), a statement that

(i) for engines that are

there were not periods during limited use stationary

which the CMS was out-ofRICE subject to

control during the reporting

numerical emission

period; or

limitations.

b. If you had a deviation from

any emission limitation or

operating limitation during

the reporting period, the

information in §63.6650(d).

If there were periods during

which the CMS, including

CEMS and CPMS, was outof-control, as specified in

§63.8(c)(7), the information

in §63.6650(e); or

i. Semiannually

according to the

requirements in

§63.6650(b) and (i).

i. Semiannually

according to the

requirements in

§63.6650(b) and (i).

c. If you had a malfunction

during the reporting period,

the information in

§63.6650(c)(4)

2.2.6.6.

The compliance report must contain the information in §63.6650(c)(1)

through (8).

[40 CFR 63.6650(c)]

2.2.6.6.1. Company name and address.

[40 CFR 63.6650(c)(1)]

2.2.6.6.2. Statement by a responsible official, with that official's name,

title, and signature, certifying the accuracy of the content of the

report.

[40 CFR 63.6650(c)(2)]

2.2.6.6.3. Date of report and beginning and ending dates of the reporting

period.

[40 CFR 63.6650(c)(3)]

2.2.6.6.4. If you had a malfunction during the reporting period, the

compliance report must include the number, duration, and a

brief description for each type of malfunction which occurred

during the reporting period and which caused or may have

caused any applicable emission limitation to be exceeded. The

report must also include a description of actions taken by an

owner or operator during a malfunction of an affected source to

minimize emissions in accordance with §63.6605(b), including

actions taken to correct a malfunction.

[40 CFR 63.6650(c)(4)]

2.2.6.6.5. If there are no deviations from any emission or operating

limitations that apply to you, a statement that there were no

deviations from the emission or operating limitations during

the reporting period.

[40 CFR 63.6650(c)(5)]

2.2.6.6.6. If there were no periods during which the continuous

monitoring system (CMS), including CEMS and CPMS, was

out-of-control, as specified in §63.8(c)(7), a statement that

there were no periods during which the CMS was out-ofcontrol during the reporting period.

[40 CFR 63.6650(c)(6)]

2.2.6.6.7. Engine site rating in brake HP, year construction of the engine

commenced (as defined in §63.2, where the exact year is not

known, provide the best estimate), and type of engine (CI, SI

2SLB, SI 4SLB, or SI 4SRB).

[40 CFR 63.6650(c)(7)]

2.2.6.6.8. Latitude and longitude of the engine in decimal degrees

reported to the fifth decimal place.

[40 CFR 63.6650(c)(8)]

2.2.6.7.

For each deviation from an emission or operating limitation occurring for

a stationary RICE where you are using a CMS to comply with the

emission and operating limitations in this subpart, you must include

information in paragraphs §63.6650(c)(1) through (4) and in

§63.6650(e)(1) through (13).

[40 CFR 63.6650(e)]

2.2.6.7.1.

The date and time that each malfunction started and stopped.

[40 CFR 63.6650(e)(1)]

2.2.6.7.2. The start and end date and time and the duration (in hours) that

each CMS was inoperative, except for zero (low-level) and

high-level checks.

[40 CFR 63.6650(e)(2)]

2.2.6.7.3. The start and end date and time and the duration (in hours) that

each CMS was out-of-control, including the information in

§63.8(c)(8).

[40 CFR 63.6650(e)(3)]

2.2.6.7.4. The date and time that each deviation started and stopped, and

whether each deviation occurred during a period of

malfunction or during another period.

[40 CFR 63.6650(e)(4)]

2.2.6.7.5. A summary of the total duration (in hours) of the deviation

during the reporting period, and the total duration as a percent

of the total source operating time during that reporting period.

[40 CFR 63.6650(e)(5)]

2.2.6.7.6. A breakdown of the total duration (in hours) of the deviations

during the reporting period into those that are due to control

equipment problems, process problems, other known causes,

and other unknown causes.

[40 CFR 63.6650(e)(6)]

2.2.6.7.7. A summary of the total duration (in hours) of CMS downtime

during the reporting period, and the total duration of CMS

downtime as a percent of the total operating time of the

stationary RICE at which the CMS downtime occurred during

that reporting period.

[40 CFR 63.6650(e)(7)]

2.2.6.7.8. An identification of each parameter and pollutant (CO or

formaldehyde) that was monitored at the stationary RICE.

[40 CFR 63.6650(e)(8)]

2.2.6.7.9. [Reserved]

[40 CFR 63.6650(e)(9)]

2.2.6.7.10. A brief description of the CMS.

[40 CFR 63.6650(e)(10)]

2.2.6.7.11. The date of the latest CMS certification or audit.

[40 CFR 63.6650(e)(11)]

2.2.6.7.12. A description of any changes in CMS, processes, or controls

since the last reporting period.

[40 CFR 63.6650(e)(12)]

2.2.6.7.13. The total operating time of the stationary RICE at which the

deviation occurred during the reporting period.

[40 CFR 63.6650(e)(13)]

2.2.6.8.

Each affected source that has obtained a title V operating permit pursuant

to 40 CFR part 70 or 71 must report all deviations as defined in this

subpart in the semiannual monitoring report required by 40 CFR 70.6

(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a

Compliance report pursuant to table 7 of this subpart along with, or as part

of, the semiannual monitoring report required by 40 CFR

70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report

includes all required information concerning deviations from any emission

or operating limitation in this subpart, submission of the Compliance

report shall be deemed to satisfy any obligation to report the same

deviations in the semiannual monitoring report. However, submission of a

Compliance report shall not otherwise affect any obligation the affected

source may have to report deviations from permit requirements to the

permit authority. Beginning on February 26, 2025, the semiannual and

annual compliance report required in table 7 of this subpart must be

submitted according to §63.6650(i). Only those elements required under

this subpart are required to be submitted according to §63.6650(i).

[40 CFR 63.6650(f)]

2.2.6.9.

Beginning on February 26, 2025 for the annual report specified in

§63.6650(h) and February 26, 2025 or one year after the report becomes

available in CEDRI, whichever is later for all other semiannual or annual

reports, submit all semiannual and annual subsequent compliance reports

using the appropriate electronic report template on the CEDRI website

(https://www.epa.gov/electronic-reporting-air-emissions/cedri) for this

subpart and following the procedure specified in §63.9(k), except any CBI

must be submitted according to the procedures in §63.6645(h). The date

report templates become available will be listed on the CEDRI website.

Unless the Administrator or delegated state agency or other authority has

approved a different schedule for submission of reports, the report must be

submitted by the deadline specified in this subpart, regardless of the

method in which the report is submitted.

[40 CFR 63.6650(i)]

2.2.6.10.

If you must comply with the emission and operating limitations, you must

keep the records described in §63.6655(a)(1) through (a)(5) and (b)(1)

through (b)(3).

[40 CFR 63.6655(a)]

2.2.6.10.1. A copy of each notification and report that you submitted to

comply with this subpart, including all documentation

supporting any Initial Notification or Notification of

Compliance Status that you submitted, according to the

requirement in §63.10(b)(2)(xiv).

[40 CFR 63.6655(a)(1)]

2.2.6.10.2. Records of the occurrence and duration (in hours) of each

malfunction of operation (i.e., process equipment) or the air

pollution control and monitoring equipment.

[40 CFR 63.6655(a)(2)]

2.2.6.10.3. Records of performance tests and performance evaluations as

required in §63.10(b)(2)(viii).

[40 CFR 63.6655(a)(3)]

2.2.6.10.4. Records of all required maintenance performed on the air

pollution control and monitoring equipment.

[40 CFR 63.6655(a)(4)]

2.2.6.10.5. Records of actions taken during periods of malfunction to

minimize emissions in accordance with §63.6605(b), including

corrective actions to restore malfunctioning process and air

pollution control and monitoring equipment to its normal or

usual manner of operation.

[40 CFR 63.6655(a)(5)]

2.2.6.11.

For each CPMS, you must keep the records listed in §63.6655(b)(1)

through (3).

[40 CFR 63.6655(b)]

2.2.6.11.1.

Records described in §63.10(b)(2)(vi) through (xi).

[40 CFR 63.6655(b)(1)]

2.2.6.11.2.

Previous (i.e., superseded) versions of the performance evaluation

plan as required in §63.8(d)(3).

[40 CFR 63.6655(b)(2)]

2.2.6.11.3.

Requests for alternatives to the relative accuracy test for CPMS as

required in §63.8(f)(6)(i), if applicable.

[40 CFR 63.6655(b)(3)]

2.2.6.12.

You must keep the records required in Table 6 of this subpart to show

continuous compliance with each emission or operating limitation that

applies.

[40 CFR 63.6655(d)]

2.2.6.13.

Records must be kept in a form suitable and readily available for

expeditious review according to §63.10(b)(1).

[40 CFR 63.6660(a)]

2.2.6.14.

As specified in §63.10(b)(1), you must keep each record for 5 years

following the date of each occurrence, measurement, maintenance,

corrective action, report, or record.

[40 CFR 63.6660(b)]

2.2.6.15.

You must keep each record readily accessible in hard copy or electronic

form for at least 5 years after the date of each occurrence, measurement,

maintenance, corrective action, report, or record, according to

§63.10(b)(1).

[40 CFR 63.6660(c)]

2.2.7.

Other Requirements and Information

2.2.7.1.

Table 8 to this subpart shows which parts of the General Provisions in

§§63.1 through 63.15

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