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 2 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 17, 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 2 Pad

SUIT Account Identification Code: 2-042

Permit Number: V-SUIT-0060-2024.02

[Replaces Permit No.: V-SUIT-0060-2024.01]

Initial Issue Date:

Revised Date:

Expiration Date:

July 15, 2025

October 8, 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

October 4, 2017

Registration

Completed 1st Part 1 Registration Requirements (40 CFR

49.101 - 49.105)

# SU-000461

December 14, 2017

Startup

Commenced Operation

# SU-000461

February 8, 2018

Registration

April 4, 2022

Registration

August 11, 2022

Registration

July 8, 2023

Registration

August 1, 2023

Startup

Completed 1 Part 2 Registration Requirements (40 CFR

49.101 - 49.105)

Completed 2nd Part 1 Registration Requirements (40 CFR

49.101 - 49.105)

Completed 2nd Part 2 Registration Requirements (40 CFR

49.101 - 49.105)

Completed 3rd Part 1 Registration Requirements (40 CFR

49.101 - 49.105)

Commenced Operation as Title V Source

# SU-000461

January 2024

Registration

Completed 3 Part 2 Registration Requirements (40 CFR

49.101 - 49.105)

# SU-000461

July 25, 2024

Application

Submitted Initial Part 70 Permit Application

N/A

July 15, 2025

Permit Issued

Initial Part 70 Permit Issued

# V-SUIT-0060-2024.00



September 9, 2025

Permit Revision



October 8, 2025

Permit Revision



Administrative Revision

Added language to 40 CFR 60, Subpart OOOOa,

due to the 2025 EPA Final Interim Rule extending

compliance deadlines for 40 CFR 60, Subpart

OOOO/a/b/c.

Minor Revision

Replacement of emission unit Gen. The

replacement engine is the same make, but a model

with lower horsepower and a different manufacture

date, resulting in a change of emissions and

applicability in accordance with 40 CFR Part 63,

Subpart ZZZZ.

Updated the ‘Responsible Official’ title in Section

I.1. - Source Information.

# V-SUIT-0060-2024.01

# V-SUIT-0060-2024.02

Table of Contents

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

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

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

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

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

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

1.1.

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

1.2.

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

1.3.

Duty to Provide and Supplement Information [RAC 2-110(7)(e), 2-106(5), and 2-124] ....................12

1.4.

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

1.5.

Severability Clause [RAC 1-106 and RAC 2-110(1)(f)] .........................................................................13

1.6.

Permit Actions [RAC 2-110(3)] ............................................................................................................ 13

1.7.

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

1.8.

Minor Permit Revisions [RAC 2-111(3)] ..............................................................................................14

1.9.

Significant Permit Revisions [RAC 2-111(4)] .......................................................................................15

1.10.

Permit Reopenings, Revocations and Reissuances, and Terminations [RAC 2-112] .........................15

1.11.

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

1.12.

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

1.13.

[Reserved] ............................................................................................................................................17

1.14.

Permit Transfers [RAC 2-113] ..............................................................................................................17

1.15.

Off-Permit Changes [RAC 2-116(2)]..................................................................................................... 17

1.16.

Permit Expiration and Renewal ..........................................................................................................18

Facility-Wide Requirements...........................................................................................................................19

2.1.

General Recordkeeping Requirements [RAC 2-110(6)] ...................................................................... 19

2.2.

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

2.3.

Alternative Operating Scenarios [RAC 2-110(8)] ................................................................................21

2.4.

Permit Shield [RAC 2-110(10)(c)].........................................................................................................23

2.5.

Stratospheric Ozone and Climate Protection [40 CFR Part 82] ..........................................................23

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 OOOOa – Standards of Performance for Crude Oil and Natural Gas

Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015,

and On or Before December 6, 2022 [40 CFR 60.5360a - 60.5439a and RAC 3-102] .......................................30

National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR Part 63 ...........................57

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] ............................................. 57

2.2.

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

Reciprocating Internal Combustion Engines [40 CFR 63.6580 – 63.6675, RAC 4-103] .....................................57

Tribal Minor New Source Review...................................................................................................................67

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-000461] ............................................................................................. 67

Reserved – Prevention of Significant Deterioration Requirements ............................................................... 67

Reserved – Consent Decree Requirements ....................................................................................................67

Reserved – Compliance Assurance Monitoring (CAM) Requirements ...........................................................67

Enhanced Monitoring, Recordkeeping, and Reporting..................................................................................67

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 ........................................................................................... 8

Section I – Source Information and Emission Unit Identification

1. Source Information

Owner Name:

SIMCOE, LLC

Facility Name:

Tiffany 2 Pad

Facility Location:

Section 17, T33N, R6W

Latitude:

37.097449 °N

Longitude:

State:

-107.528288 °W

Colorado

County:

La Plata

Responsible Official:

Midstream Superintendent

SIC Code:

1311

ICIS Identification Number:

080000000806700764

EPA Facility Registry ID:

110071293855

Other Clean Air Act Permits

Federal Implementation Plan: # SU-000461

Process Description:

The Tiffany 2 Pad produces coalbed methane natural gas. The five wells on this pad include

Tiffany 2-1, Tiffany 2-2, Tiffany 2-3, Tiffany 2-5, and Tiffany 2-6. Three wells currently utilize

artificial lift to optimize production, and the other two wells will be rodded up in the future. 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 10

million cubic feet per day with compressor inlet at about 40 pounds per square inch gauge and

compressor discharge at about 380 pounds per square inch gauge.

Emission sources at the Tiffany 2 Pad include three natural gas fired compressor engines, four

natural gas fired artificial lift engines, one natural gas fired generator engine, five natural gas

fired separator heaters, two tri-ethylene glycol dehydrators, two natural gas fired glycol reboilers,

chemical storage tanks, three produced water storage tanks, three natural gas fired tank heaters,

and fugitive components. The engines constructed at this facility are one 1,215 nameplate-rated

horsepower Waukesha L5790GL compressor engine, one 1,480 nameplate-rated horsepower

Waukesha L7042GL compressor engine, one 203 nameplate-rated horsepower Caterpillar

G3306TA compressor engine, one 72 nameplate-rated horsepower Arrow 330CF generator

engine, one 19 nameplate-rated horsepower Arrow C96 artificial lift engine, one 68 nameplaterated horsepower Arrow VRG 330 artificial lift engine, one 68 nameplate-rated horsepower

Waukesha VRG 330 artificial lift engine, and one 24.5 nameplate-rated horsepower Arrow C101

artificial lift engine.

The Caterpillar compressor engine is a rich burn engine equipped with an air to fuel ratio

controller and non-selective catalytic reduction.

2. Source Emission Points

Table 1 - Emission Units

Emission

Unit ID

Control

Equipment

Description

Waukesha L5790GL Natural Gas Fired (4SLB SI) Compressor Engine

1,215 Name Plate Rated HP

C100

Serial No.

C-12105/3

Install Date:

2023

Waukesha L7042GL Natural Gas Fired (4SLB SI) Compressor Engine

1,480 Name Plate Rated HP

C200

Serial No.

401158

Install Date:

Serial No.

07Y00232

Install Date:

2024

Arrow VRG 330 Natural Gas Fired (4SRB SI) Generator Engine

68 Name Plate Rated HP

Gen

Serial No.

P1818

Install Date:

Serial No.

LDC096001

Install Date:

Serial No.

P1819

Install Date:

Serial No.

LCC101002

Install Date:

N/A

10/10/2024

Arrow C96 Natural Gas Fired (4SRB SI) Artificial Lift Engine

19 Name Plate Rated HP

N/A

2018

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

24.5 Name Plate Rated HP

AL5

N/A

2024

Arrow VRG 330 Natural Gas Fired (4SRB SI) Artificial Lift Engine

68 Name Plate Rated HP

AL2

NSCR Catalyst

w/ AFRC

09/10/2025

Arrow C96 Natural Gas Fired (4SRB SI) Artificial Lift Engine

19 Name Plate Rated HP

AL1

N/A

2017

Caterpillar G3306TA Natural Gas Fired (4SRB SI) Compressor Engine

203 Name Plate Rated HP

C300

N/A

AL6

Serial No.

LDC095002

Install Date:

2024

Table 2 - Insignificant Emission Units

Emission Unit

Amount

Description

Size

Units

IEU-1

IEU-2

IEU-3,4

IEU-5,6,7,8,9

IEU-10,11,12

IEU-13,14,15

IEU-16,17,18

IEU-19

IEU-20,21

IEU-22,23,24,25

IEU-26

N/A

Tri-ethylene Glycol Dehydrator Still Column Vent & Flash Tank Vent

Tri-ethylene Glycol Dehydrator Reboilers

Separator Heaters

Tank Heaters

Produced Water Tanks

Lube Oil Tanks

Ethylene Glycol/Water (50/50) Tank

Tri-ethylene Glycol Tank

Lube Oil Tank

Fugitives

0.5

0.25

400

500

N/A

MMscf/d

MMBtu/hr

bbl

gal

N/A

Section II – General Requirements

1. Title V Administrative Requirements

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

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

permittee.

[RAC 2-118(2)]

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

the preceding calendar year.

[RAC 2-118(2)]

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

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

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

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

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

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

Colorado 81137.

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

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

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

Submissions section of this permit.

[RAC 2-118]

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

recent form provided by the Tribe.

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

1.1.6. Basis for calculating annual fee:

1.1.6.1.

Subtotal annual fees shall be calculated by multiplying the applicable

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

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

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

pollutant. Emissions of any regulated air pollutant that already are

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

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

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

source’s actual emissions.

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

1.1.6.1.1.

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

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

source over the preceding calendar year or any other period

determined by the Tribe to be more representative of normal

operation and consistent with the fee schedule adopted by the Tribe

and approved by the Administrator. Actual emissions shall be

calculated using each emissions units actual operating hours,

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

materials processed, stored, or combusted during the preceding

calendar year or other period used for this calculation.

[RAC 1-103(2)]

1.1.6.1.2.

Actual emissions shall be computed using compliance methods

required by the permit.

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

1.1.6.1.3.

If actual emissions cannot be determined using the compliance

methods in the permit, the permittee shall use other federally

recognized procedures.

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

1.1.6.2.

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

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

emitted from the source.

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

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

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

the start of each calendar year.]

1.1.6.3.

The permittee shall exclude the following emissions from the calculation

of fees:

1.1.6.3.1.

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

source emits in excess of 4,000 tpy.

1.1.6.3.2.

Any emissions that come from insignificant activities not required

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

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

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

completeness by a responsible official.

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

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

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

[RAC 2-118(6)]

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

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

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

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

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

Tribe along with full payment of the assessed fee.

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

1.2. Compliance Requirements

1.2.1. Compliance with the Permit

1.2.1.1.

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

permit noncompliance with federally enforceable or Commission-only

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

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

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

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

1.2.1.2.

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

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

to maintain compliance with the conditions of this permit.

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

1.2.1.3.

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

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

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

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

and conditions the permit specifically designates as not being federally

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

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

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

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

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

1.2.1.4.

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

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

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

regulations thereunder, and any other applicable law or regulation.

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

1.2.1.5.

For the purpose of submitting compliance certifications in accordance

with the Compliance Certifications condition below of this permit, or

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

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

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

a source would have been in compliance with applicable requirements if

the appropriate performance or compliance test or procedure had been

performed.

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

1.2.2. Compliance Certifications

1.2.2.1.

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

certification of compliance which shall certify the source’s compliance

status with all permit terms and conditions and all applicable requirements

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

standards, or work practices. The compliance certification shall be

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

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

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

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

annual certification of compliance will cover the period from the issuance

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

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

1.2.3. Compliance Schedule

1.2.3.1.

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

source will continue to comply with such requirements.

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

1.2.3.2.

For applicable requirements that will become effective during the permit

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

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

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

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

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

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

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

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

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

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

the provisions of RAC 2-124.

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

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

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

submittal, shall promptly submit such supplementary facts or corrected

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

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

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

[RAC 2-106(5)]

1.4. Submissions [RAC 2-105]

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

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

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

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

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

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

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

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

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

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

certifications, fee calculation worksheets, and applications for renewals and

permit modifications shall be submitted:

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)]

2. 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

1. 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 prior to July 1, 2008, and with a

maximum engine power greater than 25 brake horsepower (HP) modified 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:

C300 – Reconstructed Caterpillar G3306TA (4SRB SI) Compressor Engine, 203

Nameplate Rated HP

AL1 – Arrow C96 (4SRB SI) Artificial Lift Engine, 19 Nameplate Rated HP

AL5 – Arrow C101 (4SRB SI) Artificial Lift Engine, 24.5 Nameplate Rated HP

AL6 – Arrow C96 (4SRB SI) Artificial Lift Engine, 19 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

Manufacturing Dates

(4) At or above 225 cc

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.

Prior to July 1, 2008, for non-emergency engines with a maximum

engine power less than 500 HP.

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

1.1.2.4. 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.

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)]

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)(i), except that if you comply according to §60.4243(b)(2)(i), you

demonstrate that your non-certified engine complies with the emission

standards specified in §60.4233(f).

[40 CFR 60.4243(c)]

1.1.3.2.1.

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

combustion engine greater than 25 HP and less than or equal to

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 to demonstrate

compliance.

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

1.1.3.3.

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

Definitions

Yes

Additional terms defined in §60.4248.

§60.3

Units and abbreviations

Yes

§60.4

Address

Yes

Determination of construction

§60.5

Yes

or modification

§60.6

Review of plans

Yes

§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

§60.11

§60.12

§60.13

§60.14

§60.15

§60.16

§60.17

§60.18

§60.19

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 OOOOa – Standards of Performance for Crude Oil and

Natural Gas Facilities for which Construction, Modification or Reconstruction

Commenced After September 18, 2015, and On or Before December 6, 2022 [40

CFR 60.5360a - 60.5439a and RAC 3-102]

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

1.2.1. Affected Sources

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

60, Subpart OOOOa:

The collection of fugitive emission components located at Tiffany 2 Pad.

[40 CFR 60.5365a]

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 60.5370a(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

gas facility (e.g., individual well site, natural gas processing plant or compressor

station) and that is detected using remote detection methods and has a quantified

emission rate of 100 kg/hr of methane or greater. Upon receiving a notification of

a super emitter event issued by the EPA under §60.5371b(c) in subpart OOOOb

of this part, owners or operators must take the actions listed in paragraphs

§60.5371a(a) and (b) of this section. 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.

[40 CFR 60.5371a]

1.2.3.1.

Identification of super-emitter events.

[40 CFR 60.5371a(a)]

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 subject to the regulation under this subpart, report this

result to the EPA under paragraph §60.5371a(e) of this section.

Your super-emitter event investigation is deemed complete under

this subpart.

[40 CFR 60.5371a(a)(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,

and there is an affected facility or associated equipment subject to

this subpart onsite, you must investigate to determine the source of

the super-emitter event in accordance with paragraph

§60.5371a(a)(2) of this section, maintain records of your

investigation, and report the results in accordance with paragraph

§60.5371a(b) of this section.

[40 CFR 60.5371a(a)(2)]

1.2.3.1.3.

1.2.3.2.

The investigation required by paragraph §60.5371a(a)(2) of this

section may include but is not limited to the actions specified

below in paragraphs §60.5371a(a)(3)(i) through (iv) of this section.

[40 CFR 60.5371a(a)(3)]

1.2.3.1.3.1.

Review any maintenance activities or process activities

from the affected facilities subject to regulation under this

subpart, starting from the date of detection of the superemitter event as identified in the notification, until the date

of investigation, to determine if the activities indicate any

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

[40 CFR 60.5371a(a)(3)(i)]

1.2.3.1.3.2.

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 to

identify 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 60.5371a(a)(3)(ii)]

1.2.3.1.3.3.

If you conducted a fugitive emissions survey in accordance

with § 60.5397a 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 60.5371a(a)(3)(iii)]

1.2.3.1.3.4.

Screen the entire facility with OGI, Method 21 of appendix

A-7 to this part, or an alternative test method(s) approved

per § 60.5398b(d) of subpart OOOOb of this part, to

determine if a super-emitter event is present.

[40 CFR 60.5371a(a)(3)(iv)]

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

this section to the EPA in accordance with paragraph §60.5371a(b)(1) of

this section. If the super-emitter event (i.e., emission at 100 kg/hr of

methane or more) is ongoing at the time of this initial report, submit the

additional information in accordance with paragraph §60.5371a(b)(2) of

this section. You must attest to the information included in the report as

specified in paragraph §60.5371a(b)(3) of this section.

[40 CFR 60.5371a(b)]

1.2.3.2.1.

Within 15 days of receiving a notification from the EPA under §

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

investigation conducted under paragraph §60.5371a(a) of this

section through the Super-Emitter Program Portal, at

www.epa.gov/super-emitter. You must include the applicable

information in paragraphs §60.5371a(b)(1)(i) through (viii) of this

section 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 60.5371a(b)(1)]

1.2.3.2.1.1.

Notification Report ID of the super-emitter event

notification (which is provided in the EPA notification).

[40 CFR 60.5371a(b)(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 §60.5371a(b)(1)(iii) through

(viii) of this section.

[40 CFR 60.5371a(b)(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 60.5371a(b)(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 60.5371a(b)(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 §60.5371a(a)(2)(i) through (iv) of this section

have been conducted for all affected facilities and

associated equipment subject to regulation under this

subpart that are at this oil and natural gas facility, and you

have determined that these 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 §60.5371a(b)(1)(vi) through

(viii) of this section.

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

1.2.3.2.1.6.

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

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

1.2.3.2.1.7.

Identification of whether the source of the super-emitter

event is an affected facility or associated equipment subject

to regulation under of this subpart. If the source of the

super-emitter event is an affected facility or associated

equipment subject to regulation under this subpart, identify

the applicable regulation(s) under this subpart.

[40 CFR 60.5371a(b)(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 60.5371a(b)(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 60.5371a(b)(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 60.5371a(b)(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 Super34

Emitter Program Portal, to provide the end date and time of the

super-emitter event.

[40 CFR 60.5371a(b)(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 § 60.5371a(a) and (b).

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 60.5371a(b)(3)]

1.2.4. Fugitive Emission VOC Standards for Collection of Fugitive Emissions

Components

For each affected facility under §60.5365a(i), you must reduce GHG (in the form

of a limitation on emissions of methane) and VOC emissions by complying with

the applicable requirements of §60.5397a(a) through (j).

[40 CFR 60.5397a]

1.2.4.1.

You must monitor all fugitive emission components, as defined in

§60.5430a, in accordance with paragraphs §60.5397a(b) through (g). You

must repair all sources of fugitive emissions in accordance with

§60.5397a(h). You must keep records in accordance with §60.5397a(i) and

report in accordance with §60.5397a(j). For the purposes of this section,

fugitive emissions are defined as: Any visible emission from a fugitive

emissions component observed using optical gas imaging or an instrument

reading of 500 ppm or greater using Method 21 of appendix A-7 to this

part.

[40 CFR 60.5397a(a)]

1.2.4.2.

You must develop an emissions monitoring plan that covers the collection

of fugitive emissions components at well sites within each companydefined area in accordance with paragraphs §60.5397a(c) and (d).

[40 CFR 60.5397a(b)]

1.2.4.3.

Fugitive emissions monitoring plans must include the elements specified

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

[40 CFR 60.5397a(c)]

1.2.4.3.1.

Frequency for conducting surveys. Surveys must be conducted at

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

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

1.2.4.3.2.

Technique for determining fugitive emissions (i.e., Method 21

appendix A-7, or optical gas imaging meeting the requirements in

Paragraphs §60.5397a(c)(7)(i) through (vii).

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

1.2.4.3.3.

Manufacturer and model number of fugitive emissions detection

equipment to be used.

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

1.2.4.3.4.

Procedures and timeframes for identifying and repairing fugitive

emissions components from which fugitive emissions are detected,

including timeframes for fugitive emission components that are

unsafe to repair. Your repair schedule must meet the requirements

of paragraph §60.5397a(h) at a minimum.

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

1.2.4.3.5.

Procedures and timeframes for verifying fugitive emission

component repairs.

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

1.2.4.3.6.

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

kept.

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

1.2.4.3.7.

If you are using optical gas imaging, your plan must also include

the elements specified in paragraphs §60.5397a(c)(7)(i) through

(vii).

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

1.2.4.3.7.1.

1.2.4.3.7.1.1.

Verification that your optical gas imaging equipment meets

the specifications of paragraphs §60.5397a(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 optical gas

imaging, a fugitive emission is defined as any visible

emissions observed using optical gas imaging.

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

Your optical gas imaging equipment must be

capable of imaging gases in the spectral range for

the compound of highest concentration in the

potential fugitive emissions.

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

1.2.4.3.7.1.2.

Your optical gas imaging 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 ≤60g/hr from a quarter inch diameter orifice.

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

1.2.4.3.7.2.

Procedure for a daily verification check.

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

1.2.4.3.7.3.

Procedure for determining the operator’s maximum

viewing distance from the equipment and how the operator

will ensure that this distance is maintained.

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

1.2.4.3.7.4.

Procedure for determining maximum wind speed during

which monitoring can be performed and how the operator

will ensure monitoring occurs only at wind speeds below

this threshold.

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

1.2.4.3.7.5.

Procedures for conducting surveys, including the items

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

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

1.2.4.3.7.5.1.

How the operator will ensure an adequate thermal

background is present in order to view potential

fugitive emissions.

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

1.2.4.3.7.5.2.

How the operator will deal with adverse monitoring

conditions, such as wind.

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

1.2.4.3.7.5.3.

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

steam).

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

1.2.4.3.7.6.

Training and experience needed prior to performing

surveys.

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

1.2.4.3.7.7.

1.2.4.3.8.

Procedures for calibration and maintenance. At a minimum,

procedures must comply with those recommended by the

manufacturer.

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

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

must also include the elements specified in paragraphs

§60.5397a(c)(8)(i) through (iii). For the purposes of complying

with the fugitive emissions monitoring program using Method 21of

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

instrument reading of 500 ppm or greater.

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

1.2.4.3.8.1.

Verification that your monitoring equipment meets the

requirements specified in Section 6.0 of Method 21 at 40

CFR part 60, appendix A-7. For purposes of instrument

capability, the fugitive emissions definition shall be 500

ppm or greater methane using a FID-based instrument. If

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

instrument, you must develop a site-specific fugitive

emission definition that would be equivalent to 500 ppm

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 60.5397a(c)(8)(i)]

1.2.4.3.8.2.

Procedures for conducting surveys. At a minimum, the

procedures shall ensure that the surveys comply with the

relevant sections of Method 21 at 40 CFR part 60, appendix

A-7, including Section 8.3.1.

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

1.2.4.3.8.3.

Procedures for calibration. The instrument must be

calibrated before use each day of its use by the procedures

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

minimum, you must also conduct precision tests at the

interval specified in Method 21 of appendix A-7 of 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

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

assessments is specified in paragraphs

§60.5397(c)(8)(iii)(B) and (C).

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

1.2.4.4.

1.2.4.3.8.3.1.

Check the instrument using the same calibration gas

that was used to calibrate the instrument before use.

Follow the procedures specified in Method 21 of

appendix A-7 of 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 60.5397a(c)(8)(iii)(A)]

1.2.4.3.8.3.2.

If a calibration drift assessment shows a negative

drift of more than 10 percent, then all equipment

with instrument readings between the fugitive

emission definition multiplied by (100 minus the

percent of negative drift/divided by 100) and the

fugitive emission definition that was monitored

since the last calibration must be re-monitored.

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

1.2.4.3.8.3.3.

If any calibration drift assessment shows a positive

drift of more than 10 percent from the initial

calibration value, then, at the owner/operator's

discretion, all equipment with instrument readings

above the fugitive emission definition and below

the fugitive emission definition multiplied by (100

plus the percent of positive drift/divided by 100)

monitored since the last calibration may be remonitored.

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

Each fugitive emissions monitoring plan must include the elements

specified in paragraphs §60.5397a(d)(1) through (3), at a minimum, as

applicable.

[40 CFR 60.5397a(d)]

1.2.4.4.1.

If you are using optical gas imaging, your plan must include

procedures to ensure that all fugitive emissions components 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 60.5397a(d)(1)]

1.2.4.4.2.

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

must also 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.).

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

1.2.4.4.3.

Your fugitive emissions monitoring plan must also include the

written plan developed for all of the fugitive emission components

designated as difficult-to-monitor in accordance with paragraph

§60.5397a(g)(3), and the written plan for fugitive emission

components designated as unsafe-to-monitor in accordance with

paragraph §60.5397a(g)(4).

[40 CFR 60.5397a(d)(3)]

1.2.4.5.

Each monitoring survey shall observe each fugitive emissions component,

as defined in §60.5430a, for fugitive emissions.

[40 CFR 60.5397a(e)]

1.2.4.6.

You must conduct an initial monitoring survey within 90 days of the

startup of production, as defined in §60.5430a, for each collection of

fugitive emissions components at a new well site. For a modified

collection of fugitive emissions components at a well site, the initial

monitoring survey must be conducted within 90 days of the startup of

production for each collection of fugitive emissions components after the

modification.

[40 CFR 60.5397a(f)(1)]

1.2.4.7.

A monitoring survey of each collection of fugitive emissions components

at a well site must be performed at the frequencies specified in

§60.5397a(g)(1), with the exceptions noted in §60.5397a(g)(3) through

(5).

[40 CFR 60.5397a(g)]

1.2.4.7.1.

A monitoring survey of the collection of fugitive emissions

components at a well site must be conducted at least semiannually

after the initial survey. Consecutive semiannual monitoring

surveys must be conducted at least 4 months apart and no more

than 7 months apart.

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

1.2.4.7.2.

Fugitive emissions components that cannot be monitored without

elevating the monitoring personnel more than 2 meters above the

surface may be designated as difficult-to-monitor. Fugitive

emissions components that are designated difficult-to-monitor

must meet the specifications of paragraphs §60.5397a(g)(3)(i)

through (iv).

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

1.2.4.7.2.1.

A written plan must be developed for all of the fugitive

emissions components designated difficult-to-monitor. This

written plan must be incorporated into the fugitive

emissions monitoring plan required by paragraphs

§60.5397a(b), (c), and (d).

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

1.2.4.7.2.2.

The plan must include the identification and location of

each fugitive emissions component designated as difficultto-monitor.

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

1.2.4.7.2.3.

The plan must include an explanation of why each fugitive

emissions component designated as difficult-to-monitor is

difficult-to-monitor.

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

1.2.4.7.2.4.

The plan must include a schedule for monitoring the

difficult-to-monitor fugitive emissions components at least

once per calendar year.

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

1.2.4.7.3.

1.2.4.7.3.1.

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-tomonitor. Fugitive emissions components that are designated

unsafe-to-monitor must meet the specifications of paragraphs

§60.5397a(g)(4)(i) through (iv).

[40 CFR 60.5397a(g)(4)]

A written plan must be developed for all of the fugitive

emissions components designated unsafe-to-monitor. This

written plan must be incorporated into the fugitive

emissions monitoring plan required by paragraphs

§60.5397a(b), (c), and (d).

[40 CFR 60.5397a(g)(4)(i)]

1.2.4.7.3.2.

The plan must include the identification and location of

each fugitive emissions component designated as unsafe-tomonitor.

[40 CFR 60.5397a(g)(4)(ii)]

1.2.4.7.3.3.

The plan must include an explanation of why each fugitive

emissions component designated as unsafe-to-monitor is

unsafe-to-monitor.

[40 CFR 60.5397a(g)(4)(iii)]

1.2.4.7.3.4.

The plan must include a schedule for monitoring the

fugitive emissions components designated as unsafe-tomonitor.

[40 CFR 60.5397a(g)(4)(iv)]

1.2.4.7.4.

1.2.4.8.

You are no longer required to comply with the requirements of

§60.5397a(g)(1) when the owner or operator removes all major

production and processing equipment, as defined in §60.5430a,

such that the well site becomes a wellhead only well site. If any

major production and processing equipment is subsequently added

to the well site, then the owner or operator must comply with the

requirements in §60.5397a(f)(1) and (g)(1).

[40 CFR 60.5397a(g)(5)]

Each identified source of fugitive emissions shall be repaired, as defined

in §60.5430a, in accordance with §60.5397a(h)(1) and (2.

[40 CFR 60.5397a(h)]

1.2.4.8.1.

A first attempt at repair shall be made no later than 30 calendar

days after detection of the fugitive emissions.

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

1.2.4.8.2.

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

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

paragraph §60.5397a(h)(1).

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

1.2.4.8.3.

Delay of repair will be allowed if the conditions in

§60.5397a(h)(3)(i) or (ii) are met.

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

1.2.4.8.3.1.

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. For purposes of §60.5397a(h)(3), 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 60.5397a(h)(3)(i)]

1.2.4.8.3.2.

If the repair requires replacement of a fugitive emissions

component or a part thereof, but the replacement cannot be

acquired and installed within the repair timelines specified

in §60.5397a(h)(1) and (2) due to either of the conditions

specified in paragraphs §60.5397a(h)(3)(ii)(A) or (B), the

repair must be completed in accordance with paragraph

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

§60.5420a(c)(15)(vii)(I).

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

1.2.4.8.3.2.1.

Valve assembly supplies had been sufficiently

stocked but are depleted at the time of the required

repair.

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

1.2.4.8.3.2.2.

A replacement fugitive emissions component or a

part thereof requires custom fabrication.

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

1.2.4.8.3.2.3.

The required replacement must be ordered no later

than 10 calendar days after the first attempt at

repair. The repair must be completed as soon as

practicable, but no later than 30 calendar days after

receipt of the replacement component, unless the

repair requires a well shutdown. If the repair

requires a well shutdown, the repair must be

completed in accordance with the timeframe

specified in §60.5397a(h)(3)(i).

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

1.2.4.8.4.

Each identified source of fugitive emissions must be resurveyed to

complete repair according to the requirements in

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

emissions.

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

1.2.4.8.4.1.

The operator may resurvey the fugitive emissions

components to verify repair using either Method 21 of

appendix A–7 of this part or optical gas imaging.

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

1.2.4.8.4.2.

For each repair that cannot be made during the monitoring

survey when the fugitive emissions are initially found, a

digital photograph must be taken of that component or the

component must be tagged during the monitoring survey

when the fugitives 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 60.5397a(h)(4)(ii)]

1.2.4.8.4.3.

Operators that use Method 21 of appendix A–7 of this part

to resurvey the repaired fugitive emissions components are

subject to the resurvey provisions specified in paragraphs

§60.5397a(h)(3)(iii)(A) and (B).

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

1.2.4.8.4.3.1.

A fugitive emissions component is repaired when

the Method 21 instrument indicates a concentration

of less than 500 ppm above background or when no

soap bubbles are observed when the alternative

screening procedures specified in section 8.3.3 of

Method 21of appendix A–7 of this part are used.

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

1.2.4.8.4.3.2.

Operators must use the Method 21 monitoring

requirements specified in paragraph

§60.5397a(c)(8)(ii) or the alternative screening

procedures specified in section 8.3.3 of Method 21

of appendix A–7 of this part.

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

1.2.4.8.4.4.

Operators that use optical gas imaging to resurvey the

repaired fugitive emissions components, are subject to the

resurvey provisions specified in paragraphs

§60.5397a(h)(4)(iv)(A) and (B).

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

1.2.4.8.4.4.1.

A fugitive emissions component is repaired when

the optical gas imaging instrument shows no

indication of visible emissions.

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

1.2.4.8.4.4.2.

Operators must use the optical gas imaging

monitoring requirements specified in paragraph

§60.5397a(c)(7).

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

1.2.4.9.

Records for each monitoring survey shall be maintained as specified

§60.5420a(c)(15).

[40 CFR 60.5397a(i)]

1.2.4.10.

Annual reports shall be submitted for each collection of fugitive emissions

components at a well site that include the information specified in

§60.5420a(b)(7). Multiple collection of fugitive emissions components at

a well site may be included in a single annual report.

[40 CFR 60.5397a(j)]

1.2.5. Notification, Reporting, and Recordkeeping Requirements

1.2.5.1.

Reporting requirements. You must submit annual reports containing the

information specified in paragraphs §60.5420a(b)(1), (7), and (12). You

must submit annual reports following the procedure specified in

§60.5420a(b)(11). The initial annual report is due no later than 90 days

after the end of the initial compliance period as determined according to

§60.5410a. Subsequent annual reports are due no later than April 1 of each

year. The report due on April 1 shall cover the reporting period of January

1 – December 31 of the previous calendar year. 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 in §60.5420a(b)(1), (7), and (12). Annual reports may coincide

with title V reports as long as all the required elements of the annual report

are included.

[40 CFR 60.5420a(b) and RAC 2-110(7)]

1.2.5.1.1.

1.2.5.1.1.1.

The general information specified in §60.5420a(b)(1)(i) through

(iv) is required for all reports.

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

The company name, facility site name associated with the

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

address is not available for the site, include a description of

the site location and provide the latitude and longitude

coordinates of the site in decimal degrees to an accuracy

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

North American Datum of 1983.

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

1.2.5.1.1.2.

An identification of each affected facility being included in

the annual report.

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

1.2.5.1.1.3.

Beginning and ending dates of the reporting period.

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

1.2.5.1.1.4.

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.

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

1.2.5.1.2.

For the collection of fugitive emissions components at each well

site, report the information specified in §60.5420a(b)(7)(i) through

(iii), as applicable.

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

1.2.5.1.2.1.

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

collection of fugitive emissions components is located.

[40 CFR 60.5420a(b)(7)(i)(A)]

1.2.5.1.2.2.

For each collection of fugitive emissions components at a

well site that became an affected facility during the

reporting period, you must include the date of startup or the

date of modification.

[40 CFR 60.5420a(b)(7)(i)(B)]

1.2.5.1.2.3.

For each collection of fugitive emissions components 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 60.5420a(b)(7)(i)(D)]

1.2.5.1.2.4.

For each collection of fugitive emissions components at a

well site where 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 60.5420a(b)(7)(i)(E)]

1.2.5.1.2.5.

1.2.5.1.2.5.1.

For each fugitive emissions monitoring survey performed

during the annual reporting period, the information

specified in §60.5420a(b)(7)(ii)(A) through (G).

[40 CFR 60.5420a(b)(7)(ii)]

Date of the survey.

[40 CFR 60.5420a(b)(7)(ii)(A)]

1.2.5.1.2.5.2.

Monitoring instrument used.

[40 CFR 60.5420a(b)(7)(ii)(B)]

1.2.5.1.2.5.3.

Any deviations from the monitoring plan elements

under §60.5397a(c)(1), (2), and (7) and (c)(8)(i) or a

statement that there were no deviations from these

elements of the monitoring plan.

[40 CFR 60.5420a(b)(7)(ii)(C)]

1.2.5.1.2.5.4.

Number and type of components for which fugitive

emissions were detected.

[40 CFR 60.5420a(b)(7)(ii)(D)]

1.2.5.1.2.5.5.

Number and type of fugitive emissions components

that were not repaired as required in §60.5397a(h).

[40 CFR 60.5420a(b)(7)(ii)(E)]

1.2.5.1.2.5.6.

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 60.5420a(b)(7)(ii)(F)]

1.2.5.1.2.5.7.

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 60.5420a(b)(7)(ii)(G)]

1.2.5.1.2.6.

For each collection of fugitive emissions components at a

well site complying with an alternative fugitive emissions

standard under §60.5399a, in lieu of the information

specified in §60.5420a(b)(7)(i) and (ii), you must provide

the information specified in §60.5420a (b)(7)(iii)(A)

through (C).

[40 CFR 60.5420a(b)(7)(iii)]

1.2.5.1.2.6.1.

The alternative standard with which you are

complying.

[40 CFR 60.5420a(b)(7)(iii)(A)]

1.2.5.1.2.6.2.

The site-specific reports specified by the specific

alternative fugitive emissions standard, submitted in

the format in which they were submitted to the

state, local, or tribal authority. If the report is in

hard copy, you must scan the document and submit

it as an electronic attachment to the annual report

required in §60.5420a(b).

[40 CFR 60.5420a(b)(7)(iii)(B)]

1.2.5.1.2.6.3.

If the report specified by the specific alternative

fugitive emissions standard is not site-specific, you

must submit the information specified in §60.5420a

(b)(7)(i) and (ii) for each individual site complying

with the alternative standard.

[40 CFR 60.5420a(b)(7)(iii)(C)]

1.2.5.1.2.7.

1.2.5.1.3.

If you comply with the alternative GHG and VOC standard

under §60.5398b, in lieu of the information specified in

§60.5420a (b)(7)(ii), you must provide the information

specified in §60.5424b.

[40 CFR 60.5420a(b)(7)(iv)]

You must submit reports to the EPA via CEDRI, except as outlined

in §60.5420a(b)(11). CEDRI can be accessed through the EPA's

CDX (https://cdx.epa.gov/). You must use the appropriate

electronic report template on the CEDRI website for this subpart

(https://www.epa.gov/electronic-reporting-air-emissions/cedri/). 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 in CEDRI 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 reports must be submitted

by the deadlines specified in this subpart, regardless of the method

in which the reports are submitted. 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, submit a complete file using the

appropriate electronic report template on the CEDRI website,

including information claimed to be CBI, to the EPA following the

procedures in §60.5420a(b)(11)(i) and (ii). Clearly mark the part or

all of the information that you claim to be CBI. Information not

marked as CBI may be authorized for public release without prior

notice. Information marked as CBI will not be disclosed except in

accordance with procedures set forth in 40 CFR part 2. All CBI

claims must be asserted at the time of submission. Anything

submitted using CEDRI cannot later be claimed CBI. Furthermore,

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

confidential treatment, and the EPA is required to make emissions

data available to the public. Thus, emissions data will not be

protected as CBI and will be made publicly available. Submit the

same file submitted to the CBI office with the CBI omitted must be

submitted to the EPA via the EPA's CDX as described earlier in

§60.5420a(b)(11).

[40 CFR 60.5420a(b)(11)]

1.2.5.1.3.1.

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 above, should include

clear CBI markings. Files should be flagged to the attention

of the Oil and Natural Gas 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 60.5420a(b)(11)(i)]

1.2.5.1.3.2.

If you cannot transmit the file electronically, you may send

CBI information through the postal service to the following

address: U.S. EPA, Attn: OAQPS Document Control

Officer and Oil and Natural Gas Sector Lead, Mail Drop:

C404-02, 109 T.W. Alexander Drive, P.O. Box 12055, RTP,

NC 27711. The mailed CBI material should be double

wrapped and clearly marked. Any CBI markings should not

show through the outer envelope.

[40 CFR 60.5420a(b)(11)(ii)]

1.2.5.1.4.

If you are required to electronically submit a report through

CEDRI in the EPA's CDX, you may assert a claim of EPA system

outage for failure to timely comply with the reporting requirement.

To assert a claim of EPA system outage, you must meet the

requirements outlined in paragraphs §60.5420a(b)(13)(i) through

(vii).

[40 CFR 60.5420a(b)(13)]

1.2.5.1.4.1.

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 60.5420a(b)(13)(i)]

1.2.5.1.4.2.

The outage must have occurred within the period of time

beginning 5 business days prior to the date that the

submission is due.

[40 CFR 60.5420a(b)(13)(ii)]

1.2.5.1.4.3.

The outage may be planned or unplanned.

[40 CFR 60.5420a(b)(13)(iii)]

1.2.5.1.4.4.

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 caused a delay in reporting.

[40 CFR 60.5420a(b)(13)(iv)]

1.2.5.1.4.5.

You must provide to the Administrator a written

description identifying:

[40 CFR 60.5420a(b)(13)(v)]

1.2.5.1.4.5.1.

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

accessed and the system was unavailable;

[40 CFR 60.5420a(b)(13)(v)(A)]

1.2.5.1.4.5.2.

A rationale for attributing the delay in reporting

beyond the regulatory deadline to the EPA system

outage;

[40 CFR 60.5420a(b)(13)(v)(B)]

1.2.5.1.4.5.3.

Measures taken or to be taken to minimize the delay

in reporting; and

[40 CFR 60.5420a(b)(13)(v)(C)]

1.2.5.1.4.5.4.

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 60.5420a(b)(13)(v)(D)]

1.2.5.1.4.6.

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 60.5420a(b)(13)(vi)]

1.2.5.1.4.7.

In any circumstance, the report must be submitted

electronically as soon as possible after the outage is

resolved.

[40 CFR 60.5420a(b)(13)(vii)]

1.2.5.1.5.

If you are required to electronically submit a report through

CEDRI in the EPA's CDX, the owner or operator may assert a

claim of force majeure for failure to timely comply with the

reporting requirement. To assert a claim of force majeure, you

must meet the requirements outlined in paragraphs

§60.5420a(b)(14)(i) through (v).

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

1.2.5.1.5.1.

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 5

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 60.5420a(b)(14)(i)]

1.2.5.1.5.2.

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 caused a delay in reporting.

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

1.2.5.1.5.3.

You must provide to the Administrator:

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

1.2.5.1.5.3.1.

A written description of the force majeure event;

[40 CFR 60.5420a(b)(14)(iii)(A)]

1.2.5.1.5.3.2.

A rationale for attributing the delay in reporting

beyond the regulatory deadline to the force majeure

event;

[40 CFR 60.5420a(b)(14)(iii)(B)]

Measures taken or to be taken to minimize the delay

in reporting; and

[40 CFR 60.5420a(b)(14)(iii)(C)]

1.2.5.1.5.3.3.

1.2.5.1.5.3.4.

1.2.5.2.

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 60.5420a(b)(14)(iii)(D)]

1.2.5.1.5.4.

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 60.5420a(b)(14)(iv)]

1.2.5.1.5.5.

In any circumstance, the reporting must occur as soon as

possible after the force majeure event occurs.

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

Recordkeeping requirements. You must maintain the records identified as

specified in §60.7(f) and §60.5420a(c)(15)(i) through (ix). 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

CDX may be maintained in electronic format.

[40 CFR 60.5420a(c)]

1.2.5.2.1.

For each collection of fugitive emissions components at a well site,

maintain the records identified in §60.5420a(c)(15)(i) through

(viii).

[40 CFR 60.5420a(c)(15)]

1.2.5.2.1.1.

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

day of production after modification for each collection of

fugitive emissions components at a well site.

[40 CFR 60.5420a(c)(15)(i)]

1.2.5.2.1.2.

For each collection of fugitive emissions components 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 60.5420a(c)(15)(v)]

1.2.5.2.1.3.

The fugitive emissions monitoring plan as required in

§60.5397a(b), (c), and (d).

[40 CFR 60.5420a(c)(15)(vi)]

1.2.5.2.1.4.

The records of each monitoring survey as specified

§60.5420a(c)(15)(vii)(A) through (I).

[40 CFR 60.5420a(c)(15)(vii)]

1.2.5.2.1.4.1.

Date of the survey.

[40 CFR 60.5420a(c)(15)(vii)(A)]

1.2.5.2.1.4.2.

Beginning and end time of the survey.

[40 CFR 60.5420a(c)(15)(vii)(B)]

1.2.5.2.1.4.3.

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

operator(s) performing the survey.

[40 CFR 60.5420a(c)(15)(vii)(C)]

1.2.5.2.1.4.4.

Monitoring instrument used.

[40 CFR 60.5420a(c)(15)(vii)(D)]

1.2.5.2.1.4.5.

Fugitive emissions component identification when

Method 21 is used to perform the monitoring

survey.

[40 CFR 60.5420a(c)(15)(vii)(E)]

1.2.5.2.1.4.6.

Ambient temperature, sky conditions, and

maximum wind speed at the time of the survey.

[40 CFR 60.5420a(c)(15)(vii)(F)]

1.2.5.2.1.4.7.

Any deviations from the monitoring plan or a

statement that there were no deviations from the

monitoring plan.

[40 CFR 60.5420a(c)(15)(vii)(G)]

1.2.5.2.1.4.8.

Records of calibrations for the instrument used

during the monitoring survey.

[40 CFR 60.5420a(c)(15)(vii)(H)]

1.2.5.2.1.4.9.

Documentation of each fugitive emission detected

during the monitoring survey, including the

information specified in §60.5240a(c)(15)(vii)(I)(1)

through (9).

[40 CFR 60.5420a(c)(15)(vii)(I)]

1.2.5.2.1.4.9.1.

Location of each fugitive emission

identified.

[40 CFR 60.5420a(c)(15)(vii)(I)(1)]

1.2.5.2.1.4.9.2.

Type of fugitive emissions component,

including designation as difficult-to-monitor

or unsafe-to-monitor, if applicable.

[40 CFR 60.5420a(c)(15)(vii)(I)(2)]

1.2.5.2.1.4.9.3.

If Method 21 of appendix A–7 of this part is

used for detection, record the component ID

and instrument reading.

[40 CFR 60.5420a(c)(15)(vii)(I)(3)]

1.2.5.2.1.4.9.4.

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 60.5420a(c)(15)(vii)(I)(4)]

1.2.5.2.1.5.

1.2.5.2.1.4.9.5.

The date of first attempt at repair of the

fugitive emissions component(s).

[40 CFR 60.5420a(c)(15)(vii)(I)(5)]

1.2.5.2.1.4.9.6.

The date of successful repair of the fugitive

emissions component, including the

resurvey to verify repair and instrument used

for the resurvey.

[40 CFR 60.5420a(c)(15)(vii)(I)(6)]

1.2.5.2.1.4.9.7.

Identification of each fugitive emission

component placed on delay of repair and

explanation for each delay of repair.

[40 CFR 60.5420a(c)(15)(vii)(I)(7)]

1.2.5.2.1.4.9.8.

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 60.5420a(c)(15)(vii)(I)(8)]

1.2.5.2.1.4.9.9.

Date of planned shutdowns that occur while

there are any components that have been

placed on delay of repair.

[40 CFR 60.5420a(c)(15)(vii)(I)(9)]

For each collection of fugitive emissions components at a

well site complying with an alternative means of emissions

limitation under §60.5399a, you must maintain the records

specified by the specific alternative fugitive emissions

standard for a period of at least 5 years.

[40 CFR 60.5420a(c)(15)(viii)]

1.2.5.2.1.6.

If you comply with the alternative GHG and VOC standard

under §60.5398b, in lieu of the information specified in

§60.5420a(c)(15)(vi) through (vii), you must maintain the

records specified in §60.5424b.

[40 CFR 60.5420a(c)(15)(ix)]

1.2.6. General Provisions

1.2.6.1.

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 OOOOa of Part 60—Applicability of General Provisions to Subpart OOOOa

General

Applies to

provisions Subject of citation

Explanation

subpart?

citation

General applicability

§60.1

of the General

Yes

Provisions

§60.2

Definitions

Yes

Additional terms defined in §60.5430a.

Units and

§60.3

Yes

abbreviations

§60.4

Address

Yes

Determination of

§60.5

construction or

Yes

modification

§60.6

Review of plans

Yes

Notification and

§60.7

Yes

Except that §60.7 only applies as specified in §60.5420a(a).

record keeping

§60.8

§60.9

§60.10

§60.11

§60.12

§60.13

§60.14

Performance tests

Availability of

information

State authority

Compliance with

standards and

maintenance

requirements

Circumvention

Monitoring

requirements

Modification

Yes

Except that the format of performance test reports is described

in §60.5420a(b). Performance testing is required for control devices

used on storage vessels, centrifugal compressors, and pneumatic

pumps, except that performance testing is not required for a control

device used solely on pneumatic pump(s).

Yes

Requirements are specified in subpart OOOOa.

Yes

Continuous monitors are required for storage vessels

Yes

To the extent any provision in §60.14 conflicts with specific

provisions in subpart OOOOa, it is superseded by subpart OOOOa

provisions.

§60.15

Reconstruction

Yes

§60.16

Priority list

Incorporations by

reference

General control device

and work practice

requirements

General notification

and reporting

requirement

Yes

§60.17

§60.18

§60.19

Except that §60.15(d) does not apply to wells, pneumatic

controllers, pneumatic pumps, centrifugal compressors,

reciprocating compressors, storage vessels, or the collection of

fugitive emissions components at a well site or the collection of

fugitive emissions components at a compressor station.

Yes

[40 CFR 60.5425a]

2. 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)]

2.2. 40 CFR Part 63, Subpart ZZZZ – National Emission Standards for Hazardous Air

Pollutants for Reciprocating Internal Combustion Engines [40 CFR 63.6580 –

63.6675, RAC 4-103]

This facility is subject to the requirements of 40 CFR Part 63, Subpart ZZZZ for existing

remote stationary reciprocating internal combustion engines (RICE) with a site rating

greater than 500 brake horsepower and existing stationary RICE with a site rating of less

than 500 brake horsepower located at an area source of hazardous air pollutants (HAPs).

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

requirements of 40 CFR Part 63 Subparts A and ZZZZ.

2.2.1. Affected Sources

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

63, Subpart ZZZZ:

C-100 - Waukesha L5790GL (4SLB SI) Natural Gas-Fired Compressor Engine,

1,091 Site Rated HP

C-200 - Waukesha L7042GL (4SLB SI) Natural Gas-Fired Compressor Engine,

1,329 Site Rated HP

Gen - Arrow VRG 330 (4SRB SI) Natural Gas-Fired Generator Engine, 58 Site

Rated HP

AL2 - Arrow VRG 330 (4SRB SI) Natural Gas-Fired Artificial Lift Engine, 58

Site Rated HP

[40 CFR 63.6585 & 63.6590]

2.2.2. Emission and Operating Limitations

2.2.2.1.

If you own or operate an existing stationary RICE located at an area

source of HAP emissions, you must comply with the requirements in

Table 2d to this subpart that apply to you.

[40 CFR 63.6603(a)]

Table 2d to Subpart ZZZZ of Part 63 – Requirements for Existing Stationary RICE Located at Area

Sources of HAP Emissions

As stated in §63.6603 and §63.6640, you must comply with the following requirements for existing stationary

RICE located at area sources of HAP emissions:

For Each…

You must meet the following emission limitation,

except during periods of startup…

During periods of startup you

must…

8. Non-emergency,

non-black start 4SLB

remote stationary

RICE >500 HP

a. Change oil and filter every 2,160 hours of

operation or within 1 year + 30 days of the previous

change, whichever comes first;1

b. Inspect spark plugs every 2,160 hours of operation

or within 1 year + 30 days of the previous inspection,

whichever comes first, and replace as necessary; and

10. Non-emergency,

non-black start 4SRB

stationary RICE ≤ 500

c. Inspect all hoses and belts every 2,160 hours of

operation or within 1 year + 30 days of the previous

inspection, whichever comes first, and replace as

necessary.

a. Change oil and filter every 1,440 hours of

operation or within 1 year + 30 days of the previous

change, whichever comes first;1

Minimize the engine’s time

spent at idle and minimize the

engine’s startup time at startup

to a period needed for

appropriate and safe loading of

the engine, not to exceed 30

minutes, after which time the

non-startup emission limitations

apply.

b. Inspect spark plugs every 1,440 hours of operation

or within 1 year + 30 days of the previous inspection,

whichever comes first, and replace as necessary; and

c. Inspect all hoses and belts every 1,440 hours of

operation or within 1 year + 30 days of the previous

inspection, whichever comes first, and replace as

necessary.

Sources have the option to utilize an oil analysis program as described in §63.6625(i) or (j) in order to extend the

specified oil change requirement in Table 2d of this subpart.

2.2.2.2.

Owners and operators of existing non-emergency SI 4SLB stationary

RICE with a site rating of more than 500 HP located at area sources of

HAP that meet the definition of remote stationary RICE in §63.6675 must

evaluate the status of their stationary RICE every 12 months. Owners and

operators must keep records of the initial and annual evaluation of the

status of the engine. If the evaluation indicates that the stationary RICE no

longer meets the definition of remote stationary RICE in §63.6675, the

owner or operator must comply with all of the requirements for existing

non-emergency SI 4SLB stationary RICE with a site rating of more than

500 HP located at area sources of HAP that are not remote stationary

RICE within 1 year of the evaluation.

[40 CFR 63.6603(f)]

2.2.2.2.1.

2.2.2.2.1.1.

In accordance with §63.6675, for stationary RICE located on a

pipeline segment, Remote Stationary RICE must meet the criteria

listed below:

A pipeline segment with 10 or fewer buildings intended for

human occupancy and no buildings with four or more stories

within 220 yards (200 meters) on either side of the centerline

of any continuous 1-mile (1.6 kilometers) length of pipeline.

Each separate dwelling unit in a multiple dwelling unit

building is counted as a separate building intended for

human occupancy.

2.2.2.2.1.2.

The pipeline segment does not lie within 100 yards (91

meters) of either a building or a small, well-defined outside

area (such as a playground, recreation area, outdoor theater,

or other place of public assembly) that is occupied by 20 or

more persons on at least 5 days a week for 10 weeks in any

12-month period. The days and weeks need not be

consecutive. The building or area is considered occupied for

a full day if it is occupied for any portion of the day.

2.2.2.2.1.3.

For purposes of this section, the term pipeline segment

means all parts of those physical facilities through which gas

moves in transportation, including but not limited to pipe,

valves, and other appurtenance attached to pipe, compressor

units, metering stations, regulator stations, delivery stations,

holders, and fabricated assemblies. Stationary RICE located

within 50 yards (46 meters) of the pipeline segment

providing power for equipment on a pipeline segment are

part of the pipeline segment. Transportation of gas means the

gathering, transmission, or distribution of gas by pipeline, or

the storage of gas. A building is intended for human

occupancy if its primary use is for a purpose involving the

presence of humans.

[40 CFR 63.6603 & 63.6675]

2.2.3. General Compliance Requirements

2.2.3.1.

You must be in compliance with the emission limitations, operating

limitations, and other requirements in this subpart that apply to you at all

times.

[40 CFR 63.6605(a)]

2.2.3.1.

At all times you must operate and maintain any affected source, including

associated air pollution control equipment and monitoring equipment, in a

manner consistent with safety and good air pollution control practices for

minimizing emissions. The general duty to minimize emissions does not

require you to make any further efforts to reduce emissions if levels

required by this standard have been achieved. Determination of whether

such operation and maintenance procedures are being used will be based

on information available to the Administrator which may include, but is

not limited to, monitoring results, review of operation and maintenance

procedures, review of operation and maintenance records, and inspection

of the source.

[40 CFR 63.6605(b)]

2.2.4. Monitoring, Instillation, Collection, Operation, and Maintenance

Requirements

2.2.4.1.

You must operate and maintain the stationary RICE and after-treatment

control device (if any) according to the manufacturer's emission-related

written instructions or develop your own maintenance plan which must

provide to the extent practicable for the maintenance and operation of the

engine in a manner consistent with good air pollution control practice for

minimizing emissions:

[40 CFR 63.6625(e)]

2.2.4.2.

You must minimize the engine's time spent at idle during startup and

minimize the engine's startup time to a period needed for appropriate and

safe loading of the engine, not to exceed 30 minutes, after which time the

emission standards applicable to all times other than startup in Tables 2d

to this subpart apply.

[40 CFR 63.6625(h)]

2.2.4.3.

You have the option of utilizing an oil analysis program in order to extend

the specified oil and filter change requirement in table 2d. The oil analysis

must be performed at the same frequency specified for changing the oil

and filter in table 2d. The analysis program must at a minimum analyze

the following three parameters: Total Acid Number, viscosity, and percent

water content. The condemning limits for these parameters are as follows:

Total Acid Number increases by more than 3.0 milligrams of potassium

hydroxide (KOH) per gram from Total Acid Number of the oil when new;

viscosity of the oil has changed by more than 20 percent from the

viscosity of the oil when new; or percent water content (by volume) is

greater than 0.5. If all of these condemning limits are not exceeded, the

engine owner or operator is not required to change the oil and filter. If any

of the limits are exceeded, the engine owner or operator must change the

oil and filter within 2 business days of receiving the results of the analysis;

if the engine is not in operation when the results of the analysis are

received, the engine owner or operator must change the oil and filter

within 2 business days or before commencing operation, whichever is

later. The owner or operator must keep records of the parameters that are

analyzed as part of the program, the results of the analysis, and the oil and

filter changes for the engine. The analysis program must be part of the

maintenance plan for the engine.

[40 CFR 63.6625(j)]

2.2.5. Continuous Compliance Requirements

2.2.5.1.

You must demonstrate continuous compliance with each emission

limitation, operating limitation, and other requirements in Table 2d to this

subpart that apply to you according to methods specified in Table 6 to this

subpart.

[40 CFR 63.6640(a)]

Table 6 to Subpart ZZZZ of Part 63 – Continuous Compliance with Emission Limitations, and

Other Requirements

As stated in §63.6640, you must continuously comply with the emissions and operating limitations

and work or management practices as required by the following:

Complying with the

You must demonstrate

For Each…

requirement to…

continuous compliance by…

9. Existing non-emergency 4SLB

a. Work or Management

i. Operating and maintaining the

stationary RICE >500 HP located practices

stationary RICE according to the

at an area source of HAP that are

manufacturer's emission-related

remote stationary RICE

operation and maintenance

instructions; or

Existing non-emergency 4SRB

stationary RICE ≤500 HP located

ii. Develop and follow your own

at an area source of HAP

maintenance plan which must

provide to the extent practicable for

the maintenance and operation of

the engine in a manner consistent

with good air pollution control

practice for minimizing emissions.

2.2.5.2.

You must report each instance in which you did not meet each emission

limitation or operating limitation in Table 2d that apply to you. These

instances are deviations from the emission and operating limitations in this

subpart. These deviations must be reported according to the requirements

in §63.6650. If you change your catalyst, you must reestablish the values

of the operating parameters measured during the initial performance test.

When you reestablish the values of your operating parameters, you must

also conduct a performance test to demonstrate that you are meeting the

required emission limitation applicable to your stationary RICE.

[40 CFR 63.6640(b)]

2.2.5.3.

You must also report each instance in which you did not meet the

requirements in Table 8 to this subpart that apply to you.

[40 CFR 63.6640(e)]

2.2.6. Notifications, Reports, and Records

2.2.6.1.

If you must comply with the emission and operating limitations, you must

keep the records described in §63.6655(a)(1) through (a)(5).

[40 CFR 63.6655(a)]

2.2.6.1.1.

A copy of each notification and report that you submitted to

comply with this subpart, including all documentation supporting

any Initial Notification or Notification of Compliance Status that

you submitted, according to the requirement in §63.10(b)(2)(xiv).

[40 CFR 63.6655(a)(1)]

2.2.6.1.2.

Records of the occurrence and duration (in hours) of each

malfunction of operation (i.e., process equipment) or the air

pollution control and monitoring equipment.

[40 CFR 63.6655(a)(2)]

2.2.6.1.3.

Records of performance tests and performance evaluations as

required in §63.10(b)(2)(viii).

[40 CFR 63.6655(a)(3)]

2.2.6.1.4.

Records of all required maintenance performed on the air pollution

control and monitoring equipment.

[40 CFR 63.6655(a)(4)]

2.2.6.1.5.

Records of actions taken during periods of malfunction to

minimize emissions in accordance with §63.6605(b), including

corrective actions to restore malfunctioning process and air

pollution control and monitoring equipment to its normal or usual

manner of operation.

[40 CFR 63.6655(a)(5)]

2.2.6.2.

You must keep the records required in Table 6 of this subpart to show

continuous compliance with each emission or operating limitation that

applies to you.

[40 CFR 63.6655(d)]

2.2.6.3.

You must keep records of the maintenance conducted on the stationary

RICE in order to demonstrate that you operated and maintained the

stationary RICE and after-treatment control device (if any) according to

your own maintenance plan

[40 CFR 63.6655(e)]

2.2.6.3.1.

In order to demonstrate compliance with the maintenance

requirements, maintenance records will record the information

including, but not limited to, the following:

2.2.6.3.1.1.

Date the maintenance activity occurred.

2.2.6.3.1.2.

Hours of engine operation.

2.2.6.3.1.3.

Engine serial number.

2.2.6.3.1.4.

If an engine oil sample was pulled, if the engine oil analysis

program is allowed under §63.6625(j).

2.2.6.3.1.5.

If the engine oil was replaced.

2.2.6.3.1.6.

If the engine oil filter was replaced.

2.2.6.3.1.7.

If the belts were inspected or replaced.

2.2.6.3.1.8.

If the hoses were inspected or replaced.

2.2.6.3.1.9.

If the sparkplugs were inspected or replaced.

[RAC 2-110(6)]

2.2.6.4.

Records must be in a form suitable and readily available for expeditious

review according to §63.10(b)(1).

[40 CFR 63.6660(a)]

2.2.6.5.

As specified in §63.10(b)(1), you must keep each record for 5 years

following the date of each occurrence, measurement, maintenance,

corrective action, report, or record.

[40 CFR 63.6660(b)]

2.2.6.6.

You must keep each record readily accessible in hard copy or electronic

form for at least 5 years after the date of each occurrence, measurement,

maintenance, corrective action, report, or record, according to

§63.10(b)(1).

[40 CFR 63.6660(c)]

2.2.7. General Provisions

2.2.7.1.

Table 8 to this subpart shows which parts of the General Provisions in

§§63.1 through 63.15 apply to you.

[40 CFR 63.6665]

Table 8 to Subpart ZZZZ of Part 63—Applicability of General Provisions to Subpart ZZZZ

General

provisions

citation

§63.1

§63.2

§63.3

§63.4

Applies

Explanation

subpart

General applicability of the General Provisions Yes.

Definitions

Yes

Additional terms defined in §63.6675.

Units and abbreviations

Yes.

Prohibited activities and circumvention

Yes.

Subject of citation

§63.5

§63.6(a)

Construction and reconstruction

Applicability

Compliance dates for new and reconstructed

§63.6(b)(1)-(4)

sources

§63.6(b)(5)

Notification

Compliance dates for new and reconstructed

§63.6(b)(7)

area sources that become major sources

§63.6(c)(1)-(2)

Compliance dates for existing sources

Compliance dates for existing area sources that

§63.6(c)(5)

become major sources

§63.6(f)(2)

Methods for determining compliance

§63.6(f)(3)

Finding of compliance

§63.6(g)(1)-(3)

Use of alternate standard

§63.6(i)

Compliance extension procedures and criteria

§63.6(j)

Presidential compliance exemption

Yes.

§63.7(a)(1)-(2)

Performance test dates

Yes

§63.7(a)(3)

CAA section 114 authority

Yes.

§63.7(b)(1)

Notification of performance test

Yes

§63.7(b)(2)

Notification of rescheduling

Yes

§63.7(c)

Quality assurance/test plan

Yes

§63.7(d)

Yes.

§63.7(h)

Testing facilities

Conduct of performance tests and reduction of

data

Test run duration

Administrator may require other testing under

section 114 of the CAA

Alternative test method provisions

Performance test data analysis, recordkeeping,

and reporting

Waiver of tests

§63.8(a)(1)

Applicability of monitoring requirements

Yes

§63.7(e)(2)

§63.7(e)(3)

§63.7(e)(4)

§63.7(f)

§63.7(g)

§63.8(a)(2)

§63.8(b)(1)

Performance specifications

Monitoring

Multiple effluents and multiple monitoring

§63.8(b)(2)-(3)

systems

§63.8(c)(1)

Monitoring system operation and maintenance

§63.8(c)(1)(ii) SSM not in Startup Shutdown Malfunction Plan

§63.8(c)(2)-(3)

Monitoring system installation

§63.8(c)(4)

Continuous monitoring system (CMS)

requirements

Yes.

Yes

Subpart ZZZZ contains performance

test dates at §§63.6610, 63.6611, and

63.6612.

Except that §63.7(b)(1) only applies as

specified in §63.6645.

Except that §63.7(b)(2) only applies as

specified in §63.6645.

Except that §63.7(c) only applies as

specified in §63.6645.

Subpart ZZZZ specifies test methods

at §63.6620.

Yes.

Subpart ZZZZ contains specific

requirements for monitoring at

§63.6625.

Yes.

Yes

Except that subpart ZZZZ does not

require Continuous Opacity

Monitoring System (COMS).

§63.8(c)(6)-(8)

CMS requirements

Yes

§63.8(d)

CMS quality control

Yes.

§63.8(e)

CMS performance evaluation

Yes

§63.8(f)(1)-(5)

Alternative monitoring method

Yes

§63.8(f)(6)

Alternative to relative accuracy test

Yes

§63.8(g)

Data reduction

Yes

§63.9(a)

Applicability and State delegation of

notification requirements

Yes.

§63.9(b)(1)-(5)

Initial notifications

Yes

§63.9(c)

Request for compliance extension

Yes

§63.9(d)

Notification of special compliance requirements

for new sources

Yes

§63.9(e)

Notification of performance test

Yes

§63.9(g)(1)

Notification of performance evaluation

Yes

§63.9(g)(3)

Notification that criterion for alternative to

RATA is exceeded

Yes

§63.9(h)(1)-(6)

Notification of compliance status

Yes

§63.9(i)

§63.9(j)

Adjustment of submittal deadlines

Change in previous information

Administrative provisions for

recordkeeping/reporting

Yes.

Record retention

Yes

§63.10(a)

§63.10(b)(1)

Except for §63.8(e)(5)(ii), which

applies to COMS.

Except that §63.8(e) only applies as

specified in §63.6645.

Except that §63.8(f)(4) only applies as

specified in §63.6645.

Except that §63.8(f)(6) only applies as

specified in §63.6645.

Except that provisions for COMS are

not applicable. Averaging periods for

demonstrating compliance are

specified at §§63.6635 and 63.6640.

Except that §63.9(b)(3) is reserved.

Except that §63.9(b) only applies as

specified in §63.6645

Except that §63.9(c) only applies as

specified in §63.6645.

Except that §63.9(d) only applies as

specified in §63.6645.

Except that §63.9(e) only applies as

specified in §63.6645.

Except that §63.9(g) only applies as

specified in §63.6645.

If alternative is in use.

Except that §63.9(g) only applies as

specified in §63.6645.

Except that notifications for sources

using a CEMS are due 30 days after

completion of performance

evaluations. §63.9(h)(4) is reserved.

Except that §63.9(h) only applies as

specified in §63.6645.

Yes.

§63.10(b)(2)(vi)(xi)

§63.10(b)(2)(xii)

Records

Yes.

Record when under waiver

Yes.

§63.10(b)(2)(xiii)

Records when using alternative to RATA

Yes

§63.10(b)(2)(xiv)

§63.10(b)(3)

Records of supporting documentation

Records of applicability determination

Yes.

Except that subpart ZZZZ does not

require COMS.

Except that the most recent 2 years of

data do not have to be retained on site.

For CO standard if using RATA

alternative.

§63.10(c)

Additional records for sources using CEMS

Yes

§63.10(d)(1)

§63.10(d)(2)

§63.10(d)(4)

§63.10(e)(1) and

(2)(i)

General reporting requirements

Report of performance test results

Progress reports

Yes.

Additional CMS Reports

Yes.

§63.10(f)

§63.12

§63.13

§63.14

Excess emission and parameter exceedances

reports

Waiver for recordkeeping/reporting

State authority and delegations

Addresses

Incorporation by reference

§63.15

Availability of information

§63.10(e)(3)

Yes.

Except that §63.10(c)(2)-(4) and (9)

are reserved.

Except that §63.10(e)(3)(i) (C) is

reserved.

Yes.

3. 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-000461]

4. Reserved – Prevention of Significant Deterioration Requirements

5. Reserved – Consent Decree Requirements

6. Reserved – Compliance Assurance Monitoring (CAM) Requirements

7. 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 drive 0.45 miles. Turn north and the facility is 0.8 miles

on the north side of the road

1.2. Global Positioning System (GPS):

Latitude: 37.097449 °N

Longitude: -107.528288 °W

1.3. Safety Considerations:

SIMCOE recommends all visitors to the Tiffany 2 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.