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,

SIMCOE, LLC

Tiffany 5 Pad

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 20, T33N, R6W

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

SIMCOE, LLC

Tiffany 5 Pad

SUIT Account Identification Code: 2-041

Permit Number: V-SUIT-0059-2024.01

[Replaces Permit No.: V-SUIT-0059-2024.00]

Initial Issue Date:

Revised Date:

Expiration Date:

July 15, 2025

September 9, 2025

July 15, 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

May 19, 2022

Registration

Completed Part 1 Registration Requirements (40 CFR

49.101 - 49.105)

# SU-000485

March 9, 2023

Startup

Commenced Operation

N/A

May 8, 2023

Registration

Completed Part 2 Registration Requirements (40 CFR

49.101 - 49.105)

# SU-000485

February 5, 2024

Application

Submitted Initial Part 70 Permit Application

N/A

July 15, 2025

Permit Issued

Initial Part 70 Permit Issued

# V-SUIT-0059-2024.00



September 9, 2025

Permit Revision

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-0059-2024.01

Table of Contents

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

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

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

Source Emission Points ....................................................................................................................................6

Section II – General Requirements ......................................................................................................................... 7

Title V Administrative Requirements ...............................................................................................................7

1.1.

Annual Fee Payment [RAC 2-110(1)(h) and RAC 2-118] ........................................................................ 7

1.2.

Compliance Requirements ....................................................................................................................9

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] .....................................................................................................................11

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)] .................................................................................12

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)] .......................................................................................................15

1.12.

Inspection and Entry [RAC 2-110(9)(b)] ..............................................................................................15

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 .......................................................................................................18

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 JJJJ – Standards of Performance for Stationary Spark Ignition Internal

Combustion Engines [40 CFR 60.4230 – 60.4248, RAC 3-102] ..........................................................................23

1.2.

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, RAC 3-102] ............................................................................................................... 29

National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR Part 63 ...........................65

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 and RAC 4-103] ............................................. 66

Reserved – Tribal Minor New Source Review ................................................................................................66

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-000485] ............................................................................................. 66

Reserved – Prevention of Significant Deterioration Requirements ............................................................... 66

Reserved – Consent Decree Requirements ....................................................................................................66

Reserved – Compliance Assurance Monitoring (CAM) Requirements ...........................................................66

Enhanced Monitoring, Recordkeeping, and Reporting..................................................................................66

Section IV – Appendix .......................................................................................................................................... 68

Inspection Information ..................................................................................................................................68

1.1.

Driving Directions: ...............................................................................................................................68

1.2.

Global Positioning System (GPS): .......................................................................................................68

1.3.

Safety Considerations: ........................................................................................................................68

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:

SIMCOE, LLC

Facility Name:

Tiffany 5 Pad

Facility Location:

Section 20, T33N, R6W

Latitude:

37.084837 °N

Longitude:

State:

-107.520356 °W

Colorado

County:

La Plata

Responsible Official:

Area Manager, Midstream

SIC Code:

1311

ICIS Identification Number:

COR425767

EPA Facility Registry ID:

110071879367

Other Clean Air Act Permits

Federal Implementation Plan: # SU-000485

Process Description:

The Tiffany 5 Pad produces coalbed methane natural gas. The two wells on this pad include

Tiffany 5-2 and Tiffany 5-3. Both wells currently utilize artificial lift to optimize production. The

well streams are routed through fired separators to separate natural gas and produced water. The

gas is compressed and then sent through a tri-ethylene glycol dehydrator unit to remove

entrained water.

These wells do not produce any condensate or natural gas liquids, and the VOC content of the

produced gas is less than 0.1 percent by weight. Current production at this facility is about 12

million cubic feet per day with compressor inlet at about 90 pounds per square inch gauge and

compressor discharge at about 400 pounds per square inch gauge.

Emission sources at the Tiffany 5 Pad include one natural gas fired compressor engine, two

natural gas fired artificial lift engines, one microturbine, two natural gas fired separator heaters,

one tri-ethylene glycol dehydrator, one natural gas fired glycol reboiler, chemical storage tanks,

one produced water storage tank, one natural gas fired tank heater, and fugitive components. The

engines constructed at the facility are one 1,215 nameplate-rated horsepower Waukesha L5790

GSI compressor engine and two 24.5 nameplate-rated horsepower Arrow C101 artificial lift

engines. The compressor engine is a rich burn engine equipped with an air to fuel ratio controller

and non-selective catalytic reduction.

Source Emission Points

Table 1 - Emission Units

Emission

Unit ID

Control

Equipment

Description

Waukesha L5790 GSI (4SRB SI) Natural Gas-Fired Compressor Engine

1,215 Name Plate Rated HP

C100

Serial No.

401236

Install Date:

2023

NSCR Catalyst

w/ AFRC

Arrow C101 (4SRB SI) Natural Gas-Fired Artificial Lift Engine

24.5 Name Plate Rated HP

AL1

Serial No.

KEC101017

Install Date:

2023

AL2

Serial No.

KEC101019

Install Date:

2023

N/A

Table 2 - Insignificant Emission Units

Emission

Unit ID

Amount

IEU-1

IEU-2

IEU-3

IEU-4, 5

IEU-6

IEU-7

IEU-8

IEU-9

IEU-10

IEU-11

IEU-12, 13

IEU-14

N/A

Description

Tri-ethylene Glycol Dehydrator Still Column Vent and Flash

Tank Vent

Tri-ethylene Glycol Dehydrator Reboiler

Capstone C30 Microturbine

Separator Heater

Tank Heater

Produced Water Tank

Oily Water Sump Tank

Lube Oil Tank

Ethylene Glycol/Water (50/50) Tank

Tri-ethylene Glycol Tank

Lube Oil Tank

Fugitives

Size

Units

MMscf/d

0.50

0.125

0.25

400

500

N/A

MMBtu/hr

bbl

gal

N/A

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.

1.1.6.2.

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)]

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:

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

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

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:

1.11.

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.

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 JJJJ – Standards of Performance for Stationary Spark

Ignition Internal Combustion Engines [40 CFR 60.4230 – 60.4248, RAC 3-102]

This facility is subject to the requirements of 40 CFR Part 60, Subpart JJJJ non-emergency

stationary spark ignition (SI) internal combustion engines (ICE) with a maximum engine

power less than 25 brake horsepower (HP) manufactured on or after July 1, 2008, and

with a maximum engine power greater than 25 brake horsepower (HP) reconstructed after

June 12, 2006. Notwithstanding conditions in this permit, the permittee shall comply with

all applicable requirements of 40 CFR Part 60, Subpart A and Subpart JJJJ.

1.1.1. Affected Sources

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

60, Subpart JJJJ:

C100 – Reconstructed Waukesha L5790 GSI (4SRB SI) Compressor Engine,

1,215 Nameplate Rated HP

AL1 – Arrow C101 (4SRB SI) Artificial Lift Engine, 24.5 Nameplate Rated HP

AL2 – Arrow C101 (4SRB SI) Artificial Lift Engine, 24.5 Nameplate Rated HP

[40 CFR 60.4230]

1.1.2. Emission Standards for Owners and Operators

1.1.2.1.

Owners and operators of stationary SI ICE with a maximum engine power

less than or equal to 25 HP manufactured on or after July 1, 2008, must

comply with the emission standards in §60.4231(a) for their stationary SI

ICE

[40 CFR 60.4233(a)]

1.1.2.2.

Stationary SI internal combustion engine manufacturers must certify their

stationary SI ICE with a maximum engine power less than or equal to 25

HP manufactured on or after July 1, 2008, to the certification emission

standards and other requirements for new nonroad SI engines in 40 CFR

part 1054, as follows:

Engine Displacement

(4) At or above 225 cc

Manufacturing Dates

January 1, 2011, or later

The engine must meet the following nonhandheld emission standards identified in

40 CFR part 1054 and related

requirements:

Phase 3.

[40 CFR 60.4231(a)]

1.1.2.3.

Owners and operators of stationary SI natural gas engines that have been

modified or reconstructed after June 12, 2006, with a maximum engine

power greater than or equal to 130 HP must meet a nitrogen oxides (NO X)

emission standard of 3.0 grams per HP-hour (g/HP-hr), a CO emission

standard of 4.0 g/HP-hr (5.0 g/HP-hr for non-emergency engines less than

100 HP), and a volatile organic compounds (VOC) emission standard of

1.0 g/HP-hr, or a NOX emission standard of 250 ppmvd at 15 percent

oxygen (O2), a CO emission standard 540 ppmvd at 15 percent O2 (675

ppmvd at 15 percent O2 for non-emergency engines less than 100 HP), and

a VOC emission standard of 86 ppmvd at 15 percent O 2, where the date of

manufacture of the engine is:

[40 CFR 60.4233(f)(4)]

1.1.2.3.1.

1.1.2.4.

Prior to July 1, 2007, for non-emergency engines with a maximum

engine power greater than or equal to 500 HP.

[40 CFR 60.4233(f)(4)(i)]

After July 1, 2010, owners and operators may not install stationary SI ICE

with a maximum engine power of less than 500 HP that do not meet the

applicable requirements in §60.4233.

[40 CFR 60.4236(a)]

1.1.3. Compliance Requirements for Owners and Operators

1.1.3.1.

If you are an owner or operator of a stationary SI internal combustion

engine that is manufactured after July 1, 2008, and must comply with the

emission standards specified in §60.4233(a), you must also comply by

purchasing an engine certified to the emission standards in §60.4231(a), as

applicable, for the same engine class and maximum engine power. In

addition, you must meet one of the requirements specified in

§60.4243(a)(1) and §60.4243(a)(2).

[40 CFR 60.4243(a)]

1.1.3.1.1.

If you operate and maintain the certified stationary SI internal

combustion engine and control device according to the

manufacturer's emission-related written instructions, you must

keep records of conducted maintenance to demonstrate

compliance, but no performance testing is required if you are an

owner or operator. You must also meet the requirements as

specified in 40 CFR part 1068, subparts A through D, as they apply

to you. If you adjust engine settings according to and consistent

with the manufacturer's instructions, your stationary SI internal

combustion engine will not be considered out of compliance.

[40 CFR 60.4243(a)(1)]

1.1.3.1.2.

1.1.3.1.2.1.

1.1.3.2.

If you are an owner or operator of a stationary SI internal

combustion engine less than 100 HP, you must keep a

maintenance plan and records of conducted maintenance to

demonstrate compliance and must, to the extent practicable,

maintain and operate the engine in a manner consistent

with good air pollution control practice for minimizing

emissions, but no performance testing is required if you are

an owner or operator.

[40 CFR 60.4243(a)(2)(i)]

If you are an owner or operator of a stationary SI internal combustion

engine that must comply with the emission standards specified in

§60.4233(f), you must demonstrate compliance according to §60.4243

(b)(2)(ii).

[40 CFR 60.4243(c)]

1.1.3.2.1.

1.1.3.3.

If you do not operate and maintain the certified stationary SI

internal combustion engine and control device according to the

manufacturer's emission-related written instructions, your engine

will be considered a non-certified engine, and you must

demonstrate compliance according to §60.4243(a)(2)(i).

[40 CFR 60.4243(a)(2)]

If you are an owner or operator of a stationary SI internal

combustion engine greater than 500 HP, you must keep a

maintenance plan and records of conducted maintenance and must,

to the extent practicable, maintain and operate the engine in a

manner consistent with good air pollution control practice for

minimizing emissions. In addition, you must conduct an initial

performance test and conduct subsequent performance testing

every 8,760 hours or 3 years, whichever comes first, thereafter to

demonstrate compliance.

[40 CFR 60.4243(b)(2)(ii)]

It is expected that air-to-fuel ratio controllers will be used with the

operation of three-way catalysts/non-selective catalytic reduction. The

AFR controller must be maintained and operated appropriately in order to

ensure proper operation of the engine and control device to minimize

emissions at all times.

[40 CFR 60.4243(g)]

1.1.3.4.

If you are an owner or operator of a modified or reconstructed stationary

SI internal combustion engine and must comply with the emission

standards specified in §60.4233(f), you must demonstrate compliance

according to one of the methods specified in §60.4243(i)(1) or (2).

[40 CFR 60.4243(i)]

1.1.3.4.1.

Purchasing, or otherwise owning or operating, an engine certified

to the emission standards in §60.4233(f), as applicable.

[40 CFR 60.4243(i)(1)]

1.1.3.4.2.

Conducting a performance test to demonstrate initial compliance

with the emission standards according to the requirements

specified in §60.4244. The test must be conducted within 60 days

after the engine commences operation after the modification or

reconstruction.

[40 CFR 60.4243(i)(2)]

1.1.4. Notifications, Reports, and Records for Owners and Operators

1.1.4.1.

Owners and operators of all stationary SI ICE must keep records of the

information specified in §60.4245(a)(1) through (4).

1.1.4.1.1.

All notifications submitted to comply with this subpart and all

documentation supporting any notification.

1.1.4.1.2.

Maintenance conducted on the engine.

1.1.4.1.3.

If the stationary SI internal combustion engine is a certified engine,

documentation from the manufacturer that the engine is certified to

meet the emission standards and information as required in 40 CFR

parts 1048, 1054, and 1060, as applicable.

1.1.4.1.4.

If the stationary SI internal combustion engine is not a certified

engine or is a certified engine operating in a non-certified manner

and subject (a)(2), documentation that the engine meets the emission

standards.

[40 CFR 60.4245(a)(1-4)]

1.1.4.1.5.

Owners and operators of stationary SI ICE that are subject to

performance testing must submit a copy of each performance test as

conducted in §60.4244 within 60 days after the test has been

completed. Performance test reports using EPA Method 18, EPA

Method 320, or ASTM D6348-03 (incorporated by reference - see

40 CFR 60.17) to measure VOC require reporting of all QA/QC

data. For Method 18, report results from sections 8.4 and 11.1.1.4;

for Method 320, report results from sections 8.6.2, 9.0, and 13.0;

and for ASTM D6348-03 report results of all QA/QC procedures in

Annexes 1-7. Beginning on February 26, 2025, performance tests

must be reported electronically according to §60.4245(f).

[40 CFR 60.4245(d)]

1.1.4.1.6.

Beginning on February 26, 2025, within 60 days after the date of

completing each performance test, you must submit the results

following the procedures specified in §60.4245(g). Data collected

using test methods that are 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 an alternate electronic file.

[40 CFR 60.4245(f)]

1.1.4.1.7.

You must submit notifications or reports to the EPA via the

Compliance and Emissions Data Reporting Interface (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 §60.4245(g)(1) and (2). 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

[40 CFR 60.4245(g)]

1.1.4.1.7.1.

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 §60.4245(g),

should include clear CBI markings. ERT files should be

flagged to the attention of the Group Leader, Measurement

Policy Group; all other files should be flagged to the

attention of the Stationary Spark Ignition 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 60.4245(g)(1)]

1.1.4.1.7.2.

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. ERT files should be sent to the

attention of the Group Leader, Measurement Policy Group,

and all other files should be sent to the attention of the

Stationary Spark Ignition 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 60.4245(g)(2)]

1.1.5. General Provisions

Table 3 to this subpart shows which parts of the General Provisions in §§60.1

through 60.19 apply to you.

Table 3 to Subpart JJJJ of Part 60—Applicability of General Provisions to Subpart JJJJ

General

Applies to

provisions

Subject of citation

Explanation

subpart

citation

General applicability of the

§60.1

Yes

General Provisions

§60.2

§60.3

§60.4

Yes

§60.6

Definitions

Units and abbreviations

Address

Determination of construction

or modification

Review of plans

§60.7

Notification and Recordkeeping

Yes

§60.8

Performance tests

Yes

§60.9

§60.10

Availability of information

State Authority

Compliance with standards and

maintenance requirements

Circumvention

Monitoring requirements

Modification

Reconstruction

Priority list

Incorporations by reference

General control device

requirements

General notification and

reporting requirements

Yes

§60.5

§60.11

§60.12

§60.13

§60.14

§60.15

§60.16

§60.17

§60.18

§60.19

Additional terms defined in §60.4248.

Yes

Except that §60.7 only applies as specified in

§60.4245.

Except that §60.8 only applies to owners and

operators who are subject to performance testing in

subpart JJJJ.

Requirements are specified in subpart JJJJ.

Yes

[40 CFR 60.4246]

1.2. 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, RAC 3-102]

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

well affected facility and the collection of fugitive emissions components at a well site.

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

requirements of 40 CFR Part 60, Subpart OOOOb and Subpart A.

1.2.1. Affected Sources

Each well affected facility, which is a single well drilled for the purpose of

producing oil or natural gas.

[40 CFR 60.5365b(a)]

Each fugitive emissions components affected facility, which is the collection of

fugitive emissions components at a well site.

[40 CFR 60.5365b(i)]

1.2.2. General Requirements

1.2.2.1.

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 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)]

1.2.3. 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 superemitter 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. Paragraph §60.5371b(a) describes the qualifications one must

meet to apply to be a third-party notifier of super-emitter events. Paragraph

§60.5371b(b) describes the procedures for certifying third-party notifiers, as well

as the procedures for petitioning the Agency for removal of a third-party notifier

from the list of certified notifiers. Paragraph §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 paragraphs §60.5371b(d) and §60.5371b(e). The EPA shall post

the reports submitted under paragraph §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]

1.2.3.1.

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 paragraph §60.5371b(e).

[40 CFR 60.5371b(d)]

1.2.3.1.1.

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 paragraph

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

complete.

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

1.2.3.1.2.

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 paragraphs §60.5371b(d)(2)(i) through

(v).

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

1.2.3.1.2.1.

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 superemitter event emissions.

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

1.2.3.1.2.2.

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)]

1.2.3.1.2.3.

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)]

1.2.3.1.2.4.

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)]

1.2.3.1.2.5.

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)]

1.2.3.1.3.

1.2.3.2.

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(a)(3)]

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

EPA in accordance with paragraph §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 paragraph §60.5371b(e)(2). You must attest to the information

included in the report as specified in paragraph §60.5371b(e)(3).

[40 CFR 60.5371b(e)]

1.2.3.2.1.

Within 15 days of receiving a notification from the EPA under

paragraph §60.5371b(c), you must submit a report of the superemitter event investigation conducted under paragraph

§60.5371b(d) through the Super-Emitter Program Portal. You must

include the applicable information in paragraphs

§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)]

1.2.3.2.1.1.

Notification Report ID of the super-emitter event

notification.

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

1.2.3.2.1.2.

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 paragraphs §60.5371b(e)(1)(iii) through

(viii).

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

1.2.3.2.1.3.

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)]

1.2.3.2.1.4.

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)]

1.2.3.2.1.5.

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

paragraphs §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

paragraphs §60.5371b(e)(1)(vi) through (viii).

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

1.2.3.2.1.6.

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

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

1.2.3.2.1.7.

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)]

1.2.3.2.1.8.

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)]

1.2.3.2.1.8.1.

If the super-emitter event is not ongoing at the time

of the initial report submittal, provide the actual (or

if not known) estimated date and time the superemitter event ended.

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

1.2.3.2.1.8.2.

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)]

1.2.3.2.2.

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

submittal, within 5 business days of the date the super-emitter

event ends you must update your initial report through the SuperEmitter Program Portal to provide the end date and time of the

super-emitter event.

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

1.2.3.2.3.

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)]

1.2.4. GHG and VOC standards to well completions at well affected facilities

[The provisions of 40 CFR §60.5375 are incorporated by reference into this

permit. Please reference the CFR for an unabridged list of requirements]

1.2.4.1.

You must comply with the requirements of paragraphs §60.5375b(a)(1)

through (3) for each well completion operation with hydraulic fracturing

and refracturing at a well affected facility, except as provided in paragraph

§60.5375b(h). You must maintain a log as specified in paragraph §

60.5375b(b).

[40 CFR 60.5375b(a)]

1.2.4.2.

You must maintain a log for each well completion operation at each well

affected facility. The log must be completed on a daily basis for the

duration of the well completion operation and must contain the records

specified in §60.5420b(c)(1)(iii).

[40 CFR 60.5375b(b)]

1.2.4.3.

You must demonstrate initial compliance with the well completion

operation standards that apply to well affected facilities as required by

§60.5410b(a).

[40 CFR 60.5375b(c)]

1.2.4.4.

You must demonstrate continuous compliance with the well completion

operation standards that apply to well affected facilities as required by

§60.5415b(a).

[40 CFR 60.5375b(d)]

1.2.4.5.

You must perform the required notification, reporting and recordkeeping

as required by §60.5420b(a)(2), (b)(1) and (2), and (c)(1).

[40 CFR 60.5375b(e)]

1.2.4.6.

A well modified in accordance with §60.5365b(a)(1)(ii) (i.e., an existing

well that is hydraulically refractured) is exempt from the well completion

operation standards in paragraphs §60.5375b(b) through (d), when the

requirements of paragraphs §605375b(a)(1) through (3) are met.

[40 CFR 60.5375b(h)]

1.2.5. Standards for Gas Well Liquids Unloading Operations at Well Affected

Facilities

1.2.5.1.

General Requirements. You must comply with the requirements of this

section for each gas well liquids unloading operation at your gas well

affected facility as specified by paragraphs §60.5376b (a)(2). You have a

general duty to safely maximize resource recovery and minimize releases

to the atmosphere during gas well liquids unloading operations.

[40 CFR 60.5376b(a)]

1.2.5.1.1.

1.2.5.2.

If a gas well liquids unloading operation technology or technique

vents methane and VOC emissions to the atmosphere, you must

comply with the requirements specified in paragraphs

§60.5376b(b) and (c), or paragraph (g).

[40 CFR 60.5376b(a)(2)]

Work Practice Standards. If a gas well liquids unloading operation

employs a technology or technique that vents methane and VOC emissions

to the atmosphere, you must comply with the requirements in paragraphs

§60.5376b(b)(1) through (3) and paragraphs (c) through (f).

[40 CFR 60.5376b(b)]

1.2.5.2.1.

Employ best management practices to minimize venting of

methane and VOC emissions as specified in paragraph §60.5376b

[40 CFR 60.5376b(b)(1)]

1.2.5.2.2.

Comply with the recordkeeping requirements specified in

§60.5420b(c)(2)(ii).

[40 CFR 60.5376b(b)(2)]

1.2.5.2.3.

Submit the information specified in §60.5420b(b)(1) and (b)(3)(ii)

in the annual report.

[40 CFR 60.5376b(b)(3)]

1.2.5.3.

Best management practice requirements. For each gas well liquids

unloading operation complying with paragraphs §60.5376b(a)(2) and (b),

you must develop, maintain, and follow a best management practice plan

to minimize venting of methane and VOC emissions to the maximum

extent possible from each gas well liquids unloading operation. This best

management practice plan must meet the minimum criteria specified in

paragraphs §60.5376b(c)(1) through (4).

[40 CFR 60.5376b(c)]

1.2.5.3.1.

Include steps that create a differential pressure to minimize the

need to vent a well to unload liquids,

[40 CFR 60.5376b(c)(1)]

1.2.5.3.2.

Include steps to reduce wellbore pressure as much as possible prior

to opening the well to the atmosphere,

[40 CFR 60.5376b(c)(2)]

1.2.5.3.3.

Unload liquids through the separator where feasible, and

[40 CFR 60.5376b(c)(3)]

1.2.5.3.4.

Close all wellhead vents to the atmosphere and return the well to

production as soon as practicable.

[40 CFR 60.5376b(c)(4)]

1.2.5.4.

Initial compliance. You must demonstrate initial compliance with the

standards that apply to well liquids unloading operations at your well

affected facilities as required by §60.5410b(b).

[40 CFR 60.5376b(d)]

1.2.5.5.

Continuous compliance. You must demonstrate continuous compliance

with the standards that apply to well liquids unloading operations at your

well affected facilities as required by §60.5415b(b).

[40 CFR 60.5376b(e)]

1.2.5.6.

Recordkeeping and reporting. You must perform the required

notification, recordkeeping and reporting requirements as specified in

§60.5420b(b)(3) and (c)(2).

[40 CFR 60.5376b(f)]

1.2.6. Standards for Fugitive Emissions Components Affected Facilities

This section applies to fugitive emissions components affected facilities. You

must comply with the requirements of paragraphs §60.5397b(a) through (k) to

reduce fugitive emissions of methane and VOC.

1.2.6.1.

General requirements. You must monitor all fugitive emissions

components affected facilities in accordance with paragraphs

§60.5397b(b) through (g). You must repair all sources of fugitive

emissions in accordance with paragraph §60.5397b(h). You must

demonstrate initial compliance in accordance with paragraph

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

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

[40 CFR 60.5397b(a)]

1.2.6.2.

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

paragraphs §60.5397b(c) and (d).

[40 CFR 60.5397b(b)]

1.2.6.3.

Elements of fugitive emissions monitoring plan. Your fugitive emissions

monitoring plan must include the elements specified in paragraphs

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

[40 CFR 60.5397b(c)]

1.2.6.3.1.

Frequency for conducting surveys. Surveys must be conducted at

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

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

1.2.6.3.2.

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 paragraphs

§60.5397b(c)(7)(i) through (vii)).

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

1.2.6.3.3.

Manufacturer and model number of fugitive emissions detection

equipment to be used, if applicable.

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

1.2.6.3.4.

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 paragraph §60.5397b(h) at a minimum.

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

1.2.6.3.5.

Procedures and timeframes for verifying fugitive emission

component repairs.

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

1.2.6.3.6.

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

kept.

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

1.2.6.3.7.

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

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

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

1.2.6.3.7.1.

Verification that your OGI equipment meets the

specifications of paragraphs §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)]

1.2.6.3.7.1.1.

Your OGI equipment must be capable of imaging

gases in the spectral range for the compound of

highest concentration in the potential fugitive

emissions.

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

1.2.6.3.7.1.2.

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)]

1.2.6.3.7.2.

Procedure for a daily verification check.

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

1.2.6.3.7.3.

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)]

1.2.6.3.7.4.

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)]

1.2.6.3.7.5.

Procedures for conducting surveys, including the items

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

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

1.2.6.3.7.5.1.

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)]

1.2.6.3.7.5.2.

How the operator will deal with adverse monitoring

conditions, such as wind.

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

1.2.6.3.7.5.3.

How the operator will deal with interferences (e.g.,

steam).

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

1.2.6.3.7.6.

Training and experience needed prior to performing

surveys.

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

1.2.6.3.7.7.

Procedures for calibration and maintenance. At a minimum,

procedures must comply with those recommended by the

manufacturer.

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

1.2.6.3.8.

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

must also include the elements specified in paragraphs

§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)]

1.2.6.3.8.1.

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)]

1.2.6.3.8.2.

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)]

1.2.6.3.8.3.

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 paragraph

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

assessments is specified in paragraphs

§60.5397b(c)(8)(iii)(B) and (C).

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

1.2.6.3.8.3.1.

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)]

1.2.6.3.8.3.2.

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)]

1.2.6.3.8.3.3.

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 remonitored.

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

1.2.6.3.8.4.

1.2.6.4.

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)]

Additional elements of fugitive emissions monitoring plan. Each fugitive

emissions monitoring plan must include the elements specified in

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

[40 CFR 60.5397b(d)]

1.2.6.4.1.

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)]

1.2.6.4.2.

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 paragraph

§60.5397b(g)(2), and the written plan for fugitive emissions

components designated as unsafe-to-monitor in accordance with

paragraph §60.5397b(g)(3).

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

1.2.6.5.

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)]

1.2.6.6.

Initial monitoring survey. You must conduct initial monitoring surveys

according to the requirements specified in paragraphs §60.5397b(f)(2).

[40 CFR 60.5397b(f)]

1.2.6.6.1.

1.2.6.7.

For multi-wellhead only well sites, or well sites that contain the

major production and processing equipment specified in

paragraphs §60.5397b(g)(1)(iv) (B) or (D), you must conduct an

initial monitoring survey using OGI or Method 21 of appendix A-7

to this part within 90 days of the startup of production, for each

fugitive emissions components affected facility or by June 6, 2024

whichever date is later.

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

Monitoring frequency. A monitoring survey of each fugitive emissions

components affected facility must be performed as specified in paragraph

§60.5397b(g)(1), with the exceptions noted in paragraphs §60.5397b(g)(2)

and (3). Monitoring for fugitive emissions components affected facilities

located at well sites must continue at the specified frequencies in

paragraphs §60.5397b(g)(1)(iv) until the well closure requirements of

paragraph §60.5397b(l) are completed.

[40 CFR 60.5397b(g)]

1.2.6.7.1.

A monitoring survey of the fugitive emissions components affected

facilities must be conducted using the methods and at the

frequencies specified in paragraphs §60.5397b(g)(iv).

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

1.2.6.7.1.1.

A monitoring survey of the fugitive emissions components

affected facilities located at well sites that contain the

major production and processing equipment specified in

paragraphs §60.5397b(g)(1)(iv)(B), (C), or (D) must be

conducted at the frequencies in paragraphs

§60.5397b(g)(1)(iv)(E) and (F).

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

1.2.6.7.1.1.1.

One or more control devices.

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

1.2.6.7.1.1.2.

One or more natural gas-driven process controllers.

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

1.2.6.7.1.1.3.

Two or more pieces of major production and

processing equipment not specified in paragraphs

§60.5397b(g)(1)(iv)(B) and (C).

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

1.2.6.7.1.1.4.

A monitoring survey must be conducted at least

bimonthly 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 paragraph §60.5397b(h). A

visual inspection of all thief hatches and other

openings on storage vessels (or tank batteries) that

are fugitive emissions components must be

conducted in conjunction with the monitoring

survey to ensure that they are kept closed and sealed

at all times except during times of adding or

removing material, inspecting or sampling material,

or during required maintenance operations. If

evidence of a deviation from this requirement is

found, you must take corrective action. A visual

inspection must be conducted of all separator dump

valves to ensure the dump valve is free of debris

and not stuck in an open position must be conducted

in conjunction with the monitoring survey. Any

dump valve not operating as designed must be

repaired.

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

1.2.6.7.1.1.5.

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)(iv)(F)]

1.2.6.7.1.2.

1.2.6.7.1.2.1.

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-tomonitor. Fugitive emissions components that are

designated difficult-to-monitor must meet the specifications

of paragraphs §60.5397b(g)(2)(i) through (iv).

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

A written plan must be developed for all the

fugitive emissions components designated difficultto-monitor. This written plan must be incorporated

into the fugitive emissions monitoring plan required

by paragraphs §60.5397b(b), (c), and (d).

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

1.2.6.7.1.2.2.

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)]

1.2.6.7.1.2.3.

The plan must include an explanation of why each

fugitive emissions component designated as

difficult-to-monitor is difficult-to-monitor.

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

1.2.6.7.1.2.4.

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)]

1.2.6.7.1.3.

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-tomonitor must meet the specifications of paragraphs

§60.5397b(g)(3)(i) through (iv).

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

1.2.6.7.1.3.1.

A written plan must be developed for all the

fugitive emissions components designated unsafeto-monitor. This written plan must be incorporated

into the fugitive emissions monitoring plan required

by paragraphs §60.5397b(b), (c), and (d).

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

1.2.6.7.1.3.2.

The plan must include the identification and

location of each fugitive emissions component

designated as unsafe-to-monitor.

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

1.2.6.7.1.3.3.

The plan must include an explanation of why each

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

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

1.2.6.7.1.3.4.

1.2.6.8.

The plan must include a schedule for monitoring the

fugitive emissions components designated as

unsafe-to-monitor.

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

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

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

[40 CFR 60.5397b(h)]

1.2.6.8.1.

A first attempt at repair shall be made in accordance with

paragraphs §60.5397b(h)(1)(i) and (ii).

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

1.2.6.8.1.1.

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)]

1.2.6.8.1.2.

If you are complying with paragraph §60.5397b(g)(1)(iii)

and (iv) 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)]

1.2.6.8.2.

Repair shall be completed as soon as practicable, but no later than

15 calendar days after the first attempt at repair as required in

paragraph §60.5397b(h)(1)(i), and 30 calendar days after the first

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

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

1.2.6.8.3.

Delay of repair will be allowed if the conditions in paragraphs

§60.5397b(h)(3)(i) or (ii) are met.

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

1.2.6.8.3.1.

If the repair is technically infeasible, would require a vent

blowdown, 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 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)]

1.2.6.8.3.2.

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

conditions specified in paragraph §60.5397b(h)(3)(ii)(A) or

(B), the repair must be completed in accordance with

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

accordance with §60.5420b(c)(14)(v)(I).

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

1.2.6.8.3.2.1.

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)]

1.2.6.8.3.2.2.

A replacement fugitive emissions component or a

part thereof requires custom fabrication.

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

1.2.6.8.3.2.3.

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 paragraph §60.5397b(h)(3)(i).

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

1.2.6.8.4.

1.2.6.8.4.1.

Each identified source of fugitive emissions must be resurveyed to

complete repair according to the requirements of paragraphs

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

emissions.

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

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

paragraph §60.5397b(h)(4)(v).

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

1.2.6.8.4.2.

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)]

1.2.6.8.4.3.

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 paragraphs

§60.5397b(h)(4)(iii)(A) and (B).

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

1.2.6.8.4.3.1.

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)]

1.2.6.8.4.3.2.

Operators must use the Method 21 monitoring

requirements specified in paragraph

§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)]

1.2.6.8.4.4.

1.2.6.8.4.4.1.

Operators that use OGI to resurvey the repaired fugitive

emissions components are subject to the resurvey

provisions specified in paragraphs §60.5397b(h)(4)(iv)(A)

and (B).

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

A fugitive emissions component is repaired when

the OGI instrument shows no indication of visible

emissions.

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

1.2.6.8.4.4.2.

1.2.6.8.4.5.

Operators must use the OGI monitoring

requirements specified in paragraph

§60.5397b(c)(7).

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

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)]

1.2.6.9.

Initial compliance. You must demonstrate initial compliance with the

standards that apply to fugitive emissions components affected facilities as

required by §60.5410b(k).

[40 CFR 60.5397b(i)]

1.2.6.10.

Continuous compliance. You must demonstrate continuous compliance

with the standards that apply to fugitive emissions components affected

facilities as required by §60.5415b(l).

[40 CFR 60.5397b(j)]

1.2.6.11.

Reporting and recordkeeping. You must comply with the reporting

requirements as specified in §60.5420b(b)(1) and (9), and the

recordkeeping requirements as specified in §60.5420b(c)(16).

[40 CFR 60.5397b(k)]

1.2.7. Initial Compliance with Standards for Affected Facilities

You must determine initial compliance with the standards for each affected

facility using the requirements of paragraphs §60.5410b(b), and (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.

1.2.7.1.

Gas well liquids unloading standards for well affected facility. To

demonstrate initial compliance with the GHG and VOC standards for each

gas well liquids unloading operation conducted at your gas well affected

facility as required by §60.5376b, you must comply with paragraphs

§60.5410b(b)(1) through (3), as applicable.

[40 CFR 60.5410b(b)]

1.2.7.1.1.

You must submit the initial annual report for your well affected

facility as required in §60.5420b(b)(1) and (3).

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

1.2.7.1.2.

If you comply by using a liquids unloading technology or

technique that does not vent to the atmosphere according to

§60.5376b(a)(1), you must maintain the records specified in

§60.5420b(c)(2)(i).

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

1.2.7.1.3.

If you comply by using a liquids unloading technology or

technique that vents to the atmosphere according to

§60.5376b(a)(2), (b) and (c), you must comply with paragraphs

§60.5410(b)(3)(i) and (ii).

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

1.2.7.2.

1.2.7.1.3.1.

Employ best management practices to minimize venting of

methane and VOC emissions as specified in §60.5376b(c)

for each gas well liquids unloading operation.

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

1.2.7.1.3.2.

Maintain the records specified in §60.5420b(c)(2)(ii).

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

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 paragraphs §60.5410b(k)(1) through (5).

[40 CFR 60.5410b(k)]

1.2.7.2.1.

You must develop a fugitive emissions monitoring plan as required

in §60.5397b(b), (c), and (d).

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

1.2.7.2.2.

You must conduct an initial monitoring survey as required in

§60.5397b(e) and (f).

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

1.2.7.2.3.

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)]

1.2.7.2.4.

You must submit the initial annual report for each fugitive

emissions components affected facility as required in

§60.5420b(b)(1) and (9).

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

1.2.7.2.5.

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

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

1.2.8. Demonstrating Continuous Compliance with the Standards for Affected

Facilities.

1.2.8.1.

Gas well liquids unloading standards for well affected facility. For each

well liquids unloading operation at your well affected facility, you must

demonstrate continuous compliance with the requirements of §60.5376b

by submitting the annual report information specified in §60.5420b(b)(1)

and (3) and maintaining the records for each well liquids unloading event

specified in §60.5420b(c)(2).

[40 CFR 60.5415b(b)]

1.2.8.2.

Continuous compliance. For each fugitive emissions components affected

facility, you must demonstrate continuous compliance with the

requirements of §60.5397b(a) according to paragraphs §60.5415b(l)(1)

through (4).

[40 CFR 60.5415b(l)]

1.2.8.2.1.

Monitoring. You must conduct periodic monitoring surveys as

required in §60.5397b(e) and (g).

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

1.2.8.2.2.

Repairs. You must repair each identified source of fugitive

emissions as required in §60.5397b(h).

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

1.2.8.2.3.

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)]

1.2.8.2.4.

Records. You must maintain records as specified in

§60.5420b(c)(16).

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

1.2.9. Notification, Reporting, and Recordkeeping Requirements

1.2.9.1.

Notifications. You must submit notifications according to paragraphs

§60.5420b(a)(1) and (2) 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)]

1.2.9.1.1.

If you own or operate a well or collection of fugitive emissions

components at a well site 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)]

1.2.9.1.2.

If you own or operate a well affected facility, you must notify the

Administrator no later than 2 days prior to the commencement of

each well completion operation listing the anticipated date of the

well completion operation. The notification shall include contact

information for the owner or operator; the United States Well

Number; the latitude and longitude coordinates for each well in

decimal degrees to an accuracy and precision of five (5) decimals

of a degree using the North American Datum of 1983; and the

planned date of the beginning of flowback. You may submit the

notification in writing or in electronic format. If you are subject to

state regulations that require advance notification of well

completions and you have met those notification requirements,

then you are considered to have met the advance notification

requirements of this paragraph.

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

1.2.9.2.

Reporting requirements. You must submit annual reports containing the

information specified in paragraphs §60.5420b(b)(1), (3), (9), and (14)

following the procedure specified in paragraph §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 paragraphs

§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. You must submit the

information in paragraph §60.5420b(b)(1)(v), as applicable, for your well

affected facility which undergoes a change of ownership during the

reporting period, regardless of whether reporting under paragraphs

§60.5420b(b)(3) is required for the well affected facility.

[40 CFR 60.5420b(b)]

1.2.9.2.1.

The general information specified in paragraphs

§60.5420b(b)(1)(i) through (v) is required for all reports.

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

1.2.9.2.1.1.

The company name, facility site name associated with the

affected facility, U.S. Well ID or U.S. Well ID associated

with the affected facility, if applicable, 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)]

1.2.9.2.1.2.

An identification of each affected facility being included in

the annual report.

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

1.2.9.2.1.3.

Beginning and ending dates of the reporting period.

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

1.2.9.2.1.4.

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 §60.5420b(b)(1)(iv).

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

1.2.9.2.2.

For each well affected facility that is subject to §60.5376b(a)(2),

your annual report is required to include the information specified

in paragraphs §60.5420b(b)(3)(ii), as applicable.

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

1.2.9.2.2.1.

1.2.9.2.2.1.1.

For each well affected facility where all gas well liquids

unloading operations comply with §60.5376b(b) and (c)

best management practices, your annual report must

include the information specified in paragraphs

§60.5420b(b)(3)(ii)(A) through (E).

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

Identification of each well affected facility that

conducts a gas well liquids unloading during the

reporting period.

[40 CFR 60.5420b(b)(3)(ii)(A)]

1.2.9.2.2.1.2.

Number of liquids unloading events conducted

during the reporting period.

[40 CFR 60.5420b(b)(3)(ii)(B)]

1.2.9.2.2.1.3.

Log of best management practice plan steps used

during the reporting period to minimize emissions

to the maximum extent possible.

[40 CFR 60.5420b(b)(3)(ii)(C)]

1.2.9.2.2.1.4.

The number of liquids unloading events during the

year that best management practices were

conducted according to your best management

practice plan.

[40 CFR 60.5420b(b)(3)(ii)(D)]

1.2.9.2.2.1.5.

The number of liquids unloading events during the

year where deviations from your best management

practice plan occurred, the date and time the

deviation began, the duration of the deviation in

hours, documentation of why best management

practice plan steps were not followed, and what

steps, in lieu of your best management practice plan

steps, were followed to minimize emissions to the

maximum extent possible.

[40 CFR 60.5420b(b)(3)(ii)(E)]

1.2.9.2.3.

For the fugitive emissions components affected facility, report the

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

applicable.

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

1.2.9.2.3.1.1.

Designation of the type of site (i.e., well site) at

which the fugitive emissions components affected

facility is located.

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

1.2.9.2.3.1.2.

For the fugitive emissions components affected

facility at a well site that became an affected facility

during the reporting period, you must include the

date of the startup of production or the date of the

first day of production after modification.

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

1.2.9.2.3.1.3.

For the fugitive emissions components affected

facility at a well site, you must specify what type of

well site it is (i.e., single wellhead only well site,

small wellsite, multi-wellhead only well site, or a

well site with major production and processing

equipment).

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

1.2.9.2.3.1.4.

For the fugitive emissions components affected

facility at a well site where during the reporting

period you complete the removal of all major

production and processing equipment such that the

well site contains only one or more wellheads, you

must include the date of the change to status as a

wellhead only well site.

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

1.2.9.2.3.1.5.

For the fugitive emissions components affected

facility at a well site where you previously reported

under paragraph §60.5420b(b)(9)(i)(D) the removal

of all major production and processing equipment

and during the reporting period major production

and processing equipment is added back to the well

site, the date that the first piece of major production

and processing equipment is added back to the well

site.

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

1.2.9.2.3.1.6.

For the fugitive emissions components affected

facility at a well site where during the reporting

period you undertake well closure requirements, the

date of the cessation of production from all wells at

the well site, the date you began well closure

activities at the well site, and the dates of the

notifications submitted in accordance with

paragraph §60.5420b(a)(4).

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

1.2.9.2.3.2.

1.2.9.2.3.2.1.

For each fugitive emissions monitoring survey performed

during the annual reporting period, the information

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

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

Date of the survey.

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

1.2.9.2.3.2.2.

Monitoring instrument or, if the survey was

conducted by AVO methods, notation that AVO

was used.

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

1.2.9.2.3.2.3.

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)]

1.2.9.2.3.2.4.

Number and type of components for which fugitive

emissions were detected.

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

1.2.9.2.3.2.5.

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)]

1.2.9.2.3.2.6.

Number and type of fugitive emission components

(including designation as difficult-to-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)]

1.2.9.2.3.2.7.

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)]

1.2.9.2.4.

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

start date of the super-emitter event, the duration of the superemitter event in hours, and the affected facility associated with the

super-emitter event, if applicable.

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

1.2.9.2.5.

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)]

1.2.9.3.

Recordkeeping requirements. You must maintain the records identified as

specified in §60.7(f) and in paragraphs §60.5420b(c)(2) and (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)]

1.2.9.3.1.

For each gas well liquids unloading operation at your well affected

facility that is subject to §60.5376b(a)(2), the records of each gas

well liquids unloading operation conducted during the reporting

period, including the information specified in paragraph

§60.5420b(c)(2)(ii), as applicable.

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

1.2.9.3.1.1.

For each gas well liquids unloading operation that complies

with §60.5376b(b) and (c) best management practices,

maintain records documenting information specified in

paragraphs §60.5420b(c)(2)(ii)(A) through (D).

[40 CFR 60.5420b(c)(2)(ii)]

1.2.9.3.1.1.1.

Identification of each well affected facility that

conducts liquids unloading during the reporting

period that employs best management practices to

minimize emissions to the maximum extent

possible.

[40 CFR 60.5420b(c)(2)(ii)(A)]

1.2.9.3.1.1.2.

Documentation of your best management practice

plan developed under paragraph §60.5376b(c). You

may update your best management practice plan to

include additional steps which meet the criteria in

§60.5376b(c).

[40 CFR 60.5420b(c)(2)(ii)(B)]

1.2.9.3.1.1.3.

A log of each best management practice plan step

taken to minimize emissions to the maximum extent

possible for each gas well liquids unloading event.

[40 CFR 60.5420b(c)(2)(ii)(C)]

1.2.9.3.1.1.4.

Documentation of each gas well liquids unloading

event where deviations from your best management

practice plan steps occurred, the date and time the

deviation began, the duration of the deviation,

documentation of best management practice plan

steps not followed, and the steps taken in lieu of

your best management practice plan steps during

those events to minimize emissions to the maximum

extent possible.

[40 CFR 60.5420b(c)(2)(ii)(D)]

1.2.9.3.2.

For the fugitive emissions components affected facility, maintain

the records identified in paragraphs §60.5420b(c)(14)(i) through

(v).

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

1.2.9.3.2.1.

The date of the startup of production or the date of the first

day of production after modification for the fugitive

emissions components affected facility at a well site.

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

1.2.9.3.2.2.

For the fugitive emissions components affected facility at a

well site, you must maintain records specifying what type

of well site it is (i.e., single wellhead only well site, small

well site, multi-wellhead only well site, or a well site with

major production and processing equipment.)

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

1.2.9.3.2.3.

For the fugitive emissions components affected facility at a

well site where you complete the removal of all major

production and processing equipment such that the well site

contains only one or more wellheads, record the date the

well site completes the removal of all major production and

processing equipment from the well site, and, if the well

site is still producing, record the well ID or separate tank

battery ID receiving the production from the well site. If

major production and processing equipment is subsequently

added back to the well site, record the date that the first

piece of major production and processing equipment is

added back to the well site.

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

1.2.9.3.2.4.

The fugitive emissions monitoring plan as required in

§60.5397b(b), (c), and (d).

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

1.2.9.3.2.5.

The records of each monitoring survey as specified in

paragraphs §60.5420b(c)(14)(v)(A) through (I).

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

1.2.9.3.2.5.1.

Date of the survey.

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

1.2.9.3.2.5.2.

Beginning and end time of the survey.

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

1.2.9.3.2.5.3.

Name of operator(s), training, and experience of the

operator(s) performing the survey.

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

1.2.9.3.2.5.4.

Monitoring instrument or method used.

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

1.2.9.3.2.5.5.

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)]

1.2.9.3.2.5.6.

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)]

1.2.9.3.2.5.7.

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)]

1.2.9.3.2.5.8.

Records of calibrations for the instrument used

during the monitoring survey.

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

1.2.9.3.2.5.9.

Documentation of each fugitive emission detected

during the monitoring survey, including the

information specified in paragraphs

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

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

1.2.9.3.2.5.9.1.

Location of each fugitive emission

identified.

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

1.2.9.3.2.5.9.2.

Type of fugitive emissions component,

including designation as difficult-to-monitor

or unsafe-to-monitor, if applicable.

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

1.2.9.3.2.5.9.3.

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)]

1.2.9.3.2.5.9.4.

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)]

1.2.9.3.2.5.9.5.

The date of first attempt at repair of the

fugitive emissions component(s).

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

1.2.9.4.

1.2.9.3.2.5.9.6.

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)]

1.2.9.3.2.5.9.7.

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)]

1.2.9.3.2.5.9.8.

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)]

1.2.9.3.2.5.9.9.

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)]

Electronic reporting. If you are required to submit notifications or reports

following the procedure specified in §60.5420b(d), 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 this §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

§60.5420b(d).

[40 CFR 60.5420b(d)]

1.2.9.5.

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)]

1.2.9.5.1.

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)]

1.2.9.5.2.

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)]

1.2.9.5.3.

The outage may be planned or unplanned.

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

1.2.9.5.4.

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)]

1.2.9.5.5.

You must provide to the Administrator a written description

identifying:

[40 CFR 60.5420b(e)(5)]

1.2.9.5.5.1.

The date(s) and time(s) when CDX or CEDRI was accessed

and the system was unavailable;

[40 CFR 60.5420b(e)(5)(i)]

1.2.9.5.5.2.

A rationale for attributing the delay in reporting beyond the

regulatory deadline to EPA system outage;

[40 CFR 60.5420b(e)(5)(ii)]

1.2.9.5.5.3.

A description of measures taken or to be taken to minimize

the delay in reporting; and

[40 CFR 60.5420b(e)(5)(iii)]

1.2.9.5.5.4.

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)]

1.2.9.5.6.

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)]

1.2.9.5.7.

In any circumstance, the report must be submitted electronically as

soon as possible after the outage is resolved.

[40 CFR 60.5420b(e)(7)]

1.2.9.6.

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)]

1.2.9.6.1.

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)]

1.2.9.6.2.

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)]

1.2.9.6.3.

You must provide to the Administrator:

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

1.2.9.6.3.1.

A written description of the force majeure event;

[40 CFR 60.5420b(f)(3)(i)]

1.2.9.6.3.2.

A rationale for attributing the delay in reporting beyond the

regulatory deadline to the force majeure event;

[40 CFR 60.5420b(f)(3)(ii)]

1.2.9.6.3.3.

A description of measures taken or to be taken to minimize

the delay in reporting; and

[40 CFR 60.5420b(f)(3)(iii)]

1.2.9.6.3.4.

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)]

1.2.9.6.3.5.

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)]

1.2.9.6.3.6.

In any circumstance, the reporting must occur as soon as

possible after the force majeure event occurs.

[40 CFR 60.5420b(f)(5)]

1.2.10. 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

Subject of

provisions

Explanation

citation

subpart?

General

applicability of the

§60.1

Yes

General

Provisions

§60.2

Definitions

Yes

Additional terms defined in §60.5430b.

§60.3

Units and

Yes

§60.4

§60.5

§60.6

§60.7

§60.8

§60.9

§60.10

§60.11

§60.12

§60.13

abbreviations

Address

Determination of

construction or

modification

Review of plans

Notification and

record keeping

Performance tests

Availability of

information

State authority

Compliance with

standards and

maintenance

requirements

Circumvention

Monitoring

requirements

Yes

Modification

Yes

§60.15

Reconstruction

Yes

§60.16

Priority list

Incorporations by

reference

General control

device and work

practice

requirements

Yes

§60.18

§60.19

General

notification and

reporting

requirement

Requirements are specified in subpart OOOOb.

Yes

§60.14

§60.17

Except that §60.7 only applies as specified

in §§60.5417b(c) and 60.5420b(a).

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, wells, reciprocating compressors, process

controllers, and pumps, as applicable, except that performance

testing is not required for a control device used solely on

pump(s).

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

and RAC 4-103]

The permittee is the owner or operator of a glycol dehydration unit that is exempt from

the standards of 40 CFR §63.764(d). The permittee shall retain each determination used

to demonstrate that the actual average benzene emissions from each dehydrator are below

0.90 megagram per year.

[40 CFR 63.764(e)(1), 63.772(b), and 63.774(d)(1)]

2.1.1. The permittee must obtain an extended wet gas analysis of the inlet gas stream at

least once per calendar year. The gas sample shall be taken at a point prior to

where the gas enters the dehydration system contact tower. The analysis shall

include the gas temperature and pressure at which the sample was taken. The gas

analysis results and corresponding temperature and pressure documented during

collection of the gas sample must be used to determine the actual average benzene

emissions annually, in accordance with §63.772(b)(2)(i) or (ii). If electing to

make this demonstration according §63.772(b)(2)(i), using the GRI-GLYCalc TM

model, the permittee shall perform each model run using a single gas analysis and

the corresponding temperature and pressure documented during collection of the

gas sample. The permittee may elect to average the results of multiple GRIGLYCalcTM model runs in determining actual average benzene emissions

annually, if multiple gas samples are collected within a 12-month period.

[RAC 2-110(5)(b)]

Reserved – Tribal Minor New Source Review

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-000485]

Reserved – Prevention of Significant Deterioration Requirements

Reserved – Consent Decree Requirements

Reserved – Compliance Assurance Monitoring (CAM) Requirements

Enhanced Monitoring, Recordkeeping, and Reporting

7.1. Any documents required to be submitted under this Title V operating permit,

including but not limited to, reports, test data, monitoring data, notifications,

compliance certifications, fee calculation worksheets, and applications for renewals

and permit modifications shall be submitted to the Tribe:

by email at: airqualty@southernute-nsn.gov

or by United States Postal Service:

or by Common Carrier:

Part 70 Program

Environmental Programs Department

Air Quality Division

P.O. Box 737 MS #84

Ignacio, Colorado 81137

Part 70 Program

Environmental Programs Department

Air Quality Division

398 Ouray Drive

Ignacio, CO 81137

Section IV – Appendix

Inspection Information

1.1. Driving Directions:

From the intersection of CO 172 and CO 151 in Ignacio, head east on CO 151 for 6.5

miles. Turn east on SU 159, and the facility is 0.7 miles down on the south side of the

road.

1.2. Global Positioning System (GPS):

Latitude: 37.084837 °N

Longitude: -107.520356 °W

1.3. Safety Considerations:

SIMCOE recommends all visitors to the Tiffany 5 Pad wear a hard hat, safety glasses,

safety footwear, hearing protection, and fire-retardant clothing

This is a copy of a public record, reproduced as it was published. It is not legal advice, and it may not be the version a court would rely on. Check the official source before you cite it.