matador’s...matador production company tom matthews facility july, 2020 gcp-oil and gas form: 10...

_____________________________________________________________________________________

1501 Bill Owens Parkway ● Longview, Texas 75604 ● T 903.297.4673 ● F 903.297.4675 www.sphere3env.com

Date: July 20th, 2020

To: New Mexico Environmental Department Via FEDEX

Air Quality Bureau

525 Camino de los Marquez, Suite No. 1

Santa Fe, New Mexico 87505-1816

Subject: General Construction Permit (GCP) Oil and Gas Application Update

Matador Production Company

Tom Matthews Facility

Malaga, Eddy County, New Mexico

To Whom It May Concern:

On behalf of Matador Production Company (Matador), Sphere 3 Environmental (Sphere 3) respectfully

submits this General Construction Permit (GCP Oil and Gas) application update (GCP-7731M1) for the

Tom Matthews Facility located in Eddy County, New Mexico.

The Client believes the Project and its associated air emissions qualify for an GCP Oil and Gas permit

under the New Mexico Air Code 20.2.72 for oil and gas facilities. This letter and the following

attachments constitute Matador’s GCP Oil and Gas registration submittal to the New Mexico

Environment Department (NMED) for review and approval.

We would like to thank you in advance for your review and concurrence with this GCP Oil and Gas

application. If you should have any questions regarding the information presented in this letter or

attachments, please contact me at (903) 297-4673 or via email at [email protected].

Best Regards,

Sphere 3 Environmental, Inc.

Janna Loeppky

Environmental Scientist

Attachments

cc: Matador Production Company

July, 2020

Sphere 3 Project No. 049014.00

Tom Matthews Facility General Construction Permit (GCP Oil and Gas)

Application Update

Eddy County, New Mexico

Prepared for:

Casey Snow Matador Production Company

5400 LBJ Freeway, Suite 1500

Dallas, Texas 75240

972-371-5439

Prepared by:

Janna Loeppky Sphere 3 Environmental, Inc.

1501 Bill Owens Parkway

Longview, Texas 75604

(903) 297-4673

1

Matador Production Company Tom Matthews Facility July, 2020

GCP-Oil and Gas Form: 10 December 2019

Mail Registration To:

New Mexico Environment Department

Air Quality Bureau

525 Camino de los Marquez, Suite 1

Santa Fe, New Mexico, 87505

Phone (505) 476-4300

Fax (505) 476-4375 www.env.nm.gov/aqb

For Department use only:

General Construction Permit (GCP-Oil and Gas)

Registration Form

Section 1 (Locating outside of Bernalillo County, Tribal Lands, and Nonattainment Areas)

This Registration is being submitted as (check all that apply): An initial GCP-Oil and Gas Registration Form for a new facility (Registration fee required).

An updated GCP-Oil and Gas Registration Form for a modification to an existing facility (Registration fee required).

A GCP-Oil and Gas Registration Form for an existing facility currently operating under GCP-1 or GCP-4 (No fee required)

The Permitting Administrative Multi-Form may be used for administrative changes identified in the GCP O&G Permit Condition

C101.A. No public notification is required, and no filing fees or permit fees apply.

Construction Status: Not Constructed X Existing Permitted (or NOI) Facility Existing Non-Permitted (or NOI) Facility

Acknowledgements: I acknowledge that a pre-application meeting is available to me upon request.

An original signed and notarized Certification for Submittal for this GCP-Oil and Gas Registration is included.

Proof of public notice is included, if required.

The Air Emission Calculation Tool (AECT) is included.

The emissions specified in this Registration Form will establish the emission limits in the GCP-Oil and Gas.

For new registrations or modifications, a check for the registration fee is included for $4190 prior to 1/1/20 or $4260

beginning 1/1/20. There is an annual fee in addition to the registration fee: www.env.nm.gov/air-quality/permit-fees-2/

Facilities qualifying as a “small business” under 20.2.75.7.F NMAC qualify for reduced fees, provided that NMED has a Small

Business Certification Form from your company on file. This form can be found at:

www.env.nm.gov/aqb/sbap/Small_Business_Forms.html

Provide your Check Number: __0010032228____ and Amount: __$4260.00___

If a fee is required and is not submitted with the application, the registration will be denied.

1) Company Information AI # (if

known): 38327

If updating,

provide

Permit/NOI #:

7731M1

1 Facility Name: Tom Matthews Facility

Plant primary SIC Code (4 digits): 1311

Plant NAIC code (6 digits): 211130

a Facility Street Address (If no facility street address, check here and provide directions in Section 4):

2 Plant Operator Company Name: Matador Production Company Phone/Fax: 972-371-5200

2

http://www.env.nm.gov/aqbhttp://www.env.nm.gov/air-quality/permit-fees-2/http://www.env.nm.gov/aqb/sbap/Small_Business_Forms.html



a Plant Operator Address: 5400 LBJ Freeway, Suite 1500, Dallas, Texas 75240

3 Plant Owner(s) name(s): Matador Production Company Phone/Fax: 972-371-5200

a Plant Owner(s) Mailing Address(s): 5400 LBJ Freeway, Suite 1500, Dallas, Texas 75240

4 Bill To (Company): Matador Production Company Phone/Fax: 972-371-5200

a Mailing Address: 5400 LBJ Freeway, Suite 1500, Dallas, Texas 75240 E-mail: [email protected]

5 Preparer: Janna Loeppky

Consultant: Sphere 3 Environmental, Inc. Phone/Fax: 903-297-4673

a Mailing Address: 1501 Bill Owens Parkway, Longview, Texas 75604 E-mail: [email protected]

6 Plant Operator Contact: Mr. Casey Snow Phone/Fax: 972-371-5239

a Mailing Address: 5400 LBJ Freeway, Suite 1500, Dallas, Texas 75240 E-mail: [email protected]

7 Air Permit Contact1: Mr. Casey Snow Title: VP-Regulatory, Environmental & Safety

a E-mail: [email protected] Phone/Fax: 972-371-5239

b Mailing Address: 5400 LBJ Freeway, Suite 1500, Dallas, Texas 75240

1The Air Permit Contact will receive official correspondence from the Department.

8 Will this facility operate in conjunction with other air regulated parties on the same property? No Yes

If yes, what is the name and NOI or permit number (if known) of the other facility?

2) Applicability

1 Is the facility located in Bernalillo County, on tribal lands, or in a nonattainment area? No

Yes

If you answered Yes to the question above, your facility does not qualify for this general construction permit.

2 Is the facility’s SIC code 1311, 1321, 4619, 4612 or 4922? (Other SIC codes may be approved provided that

all the equipment at the facility is allowed in the GCP-Oil & Gas Permit.)

No

Yes

3 Does the regulated equipment under this GCP-Oil and Gas Registration include any combination of

Allowable Equipment listed in Table 104 of the GCP Oil & Gas Permit, and no others?

No

Yes

4 Will the regulated equipment as specified in this GCP-Oil and Gas Registration emit less than the total

emissions in Table 106 of the GCP-Oil and Gas permit?

No

Yes

5 Does all equipment comply with the stack parameter requirements as established in the GCP-Oil and Gas

Permit?

No

Yes

6 Equipment shall be at least 100 meters (m) from any stack to terrain that is five (5) or more meters above the

top of the stack. Will the equipment at the facility meet this terrain requirement?

No

Yes

7 Is the facility at least 150 m from any source that emits over 25 tons/year of NOx? This is the distance

between the two nearest stacks that emit NOx at each of the facilities. Not the facility boundaries or the

center to center distances.

No

Yes

8 Is the facility at least 3 miles from any Class I area? This is the distance from the nearest facility boundary to

the nearest boundary of the Class I area.

No

Yes

If you answered NO to any of questions 2-8, your facility does not qualify for this general construction permit.

3) Current Facility Status

1 Has this facility already been constructed? Yes No If yes, is it currently operating in New Mexico? Yes

No

2 Does this facility currently have a construction permit or Notice of Intent

(NOI) (20.2.72 NMAC or 20.2.73 NMAC)? Yes No

If yes, the permit No. or NOI No., and whether

it will remain active or not: 7731M1

3 Is this Registration in response to a Notice of Violation (NOV)?

Yes No If so, provide current permit #:

If yes, NOV date:

NOV Tracking No.

4 Check if facility is a:

Minor Source: Synthetic Minor Source: (SM80 = Controlled Emissions > 80 TPY of any regulated air pollutant):

3

mailto:[email protected]:[email protected]:[email protected]:[email protected]



4) Facility Location Information

1 a) Latitude (decimal degrees):

32.230007

b) Longitude (decimal degrees):

-104.085259 c) County: Eddy d) Elevation (ft): 3021

2 a) UTM Zone: 12 or 13 b) UTME (to nearest 10 meters): 586187 c) UTMN (to nearest 10 meters): 3566298

3 e) Specify which datum is used: NAD 27 NAD 83 WGS 84

See this link for more info. http://en.wikipedia.org/wiki/North_American_Datum

4 Name and zip code of nearest New Mexico town and tribal community: Malaga, 88256

5 Detailed Driving Instructions including direction and distance from nearest NM town and tribal community (attach a road

map if necessary). If there is no street address, provide public road mileage marker: From Malaga, travel northeast on UW

Highway 285 for 0.5 miles. Turn left onto an unnamed access road and travel west for 0.5 miles. Keep left. The facility is

located on the left.

6 The facility is 0.9 (distance) miles northwest (direction) of Malaga (nearest town).

7 Land Status of facility (check one): Private Indian/Pueblo Government BLM Forest Service

Military

5) Other Facility Information

1 Enter the maximum daily and annual throughput of oil,

gas, and natural gas liquids (NGL).

Oil (bbl/day): 300.0 (bbl/yr): 109,500.0

Gas (MMscf/day): 2.8 (MMscf/yr): 1,022.0

NGL (bbl/day): N/A (bbl/yr): N/A

2 The facility, as described in this Registration, constitutes

the entire source for 20.2.70, 20.2.72, 20.2.73, or 20.2.74

NMAC applicability purposes.

No Yes

6) Submittal Requirements

1 Include one hard copy original signed and notarized Registration package printed double sided ‘head-to-toe’ 2-hole

punched as we bind the document on top, not on the side; except landscape tables, which should be head-to-head. If ‘head-

to-toe printing’ is not possible, print single sided. Please use numbered tab separators in the hard copy submittal(s) as

this facilitates the review process.

2 Include one double sided hard copy, flip on long edge for Department use. This copy does not need to be 2-hole punched.

3 The entire Registration package should be submitted electronically on one compact disk (CD). Include a single PDF

document of the entire Registration as submitted and the individual documents comprising the Registration. The documents

should also be submitted in Microsoft Office compatible file format (Word, Excel, etc.) allowing us to access the text in the

documents (copy & paste). Any documents that cannot be submitted in a Microsoft Office compatible format shall be saved

as a PDF file from within the electronic document that created the file. If you are unable to provide Microsoft office

compatible electronic files or internally generated PDFs of files (items that were not created electronically: i.e. brochures,

maps, graphics, etc.), submit these items in hard copy format. Spreadsheets must be unlocked since we must be able to

review the formulas and inputs.

Ensure all of these are included in both the electronic and hard copies.

Word Document part of the Registration Form (Sections 1 and 3-10)

Excel Document part of the Registration Form (Section 2)

Air Emissions Calculation Tool (AECT) If there is a justified reason for including other calculations, include the

unlocked Excel Spreadsheet. Justification must be provided in Section 5 of the application.

PDF of entire application

To avoid errors, it is best to start with both a blank version of this form and the AECT for each application.

4

http://en.wikipedia.org/wiki/North_American_Datum

Matador Production Company Tom Matthews Facility July, 2020; Revision No.2

Permit No.

Permit Mechanism:

Authorization Date:

Equipment Unit No. Description Serial Number/Identifier Equipment Unit No. Description Serial Number/Identifier

ENG-1 Engine-1

G3516ULB (SN:

N6W00290) ENG-1 Engine-1

G3516ULB (SN:

N6W00290)

ENG-2 Engine-2 GJ230 (SN: FI-50149) N/A N/A N/A

GEN-1 Generator-1 D111L (SN: EEIOH404150) GEN-1 Generator-1 D111L (SN: EEIOH807865)

HT-1

Heater Treater-

1 0.5 MMBTU/hr HT-1

Heater

Treater-1 0.5 MMBTU/hr

HT-2

Heater Treater-

2 0.5 MMBTU/hr HT-2

Heater

Treater-2 0.5 MMBTU/hr

VRU-1

Vapor

Recovery Unit-

1 N/A N/A N/A N/A

OT-1 Oil Tank-1 400 BBL OT-1 Oil Tank-1 400 BBL



OLOAD-1

Oil Truck

Loading N/A OLOAD-1

Oil Truck

Loading-1 N/A

SSM-1

Startup,

Shutdown &

Maintenance N/A SSM-1

Startup,

Shutdown &

Maintenance N/A

Malf. Malfuction N/A Malf.-1 Malfuction N/A

PWT-1

Produced

Water Tank-1 400 BBL PWT-1

Produced

Water Tank-1 400 BBL

PWT-2

Produced


Produced


PWT-3

Produced


Produced


PWLOAD-1

Produced

Water Truck

Loading N/A PWLOAD-1

Produced

Water Truck

Loading N/A

FL-1 Flare-1 ICTDUF-10/ICF-1091 FL-1 Flare-1 ICTDUF-10/0.2/ICF-1091

FUG-1 Fugitives N/A FUG-1 Fugitives N/A

HR-1

Unpaved Haul

Road N/A HR-1

Unpaved

Haul Road N/A

TP 1-2

Transfer

Pumps 1-2 Wilden P8

Existing (unchanged)




New/Additional




New/Proposed Registration

Table A. Equipment Cross Reference

Updated Equipment Unit Number:

Equipment listed below correlates to previously represented unit numbers. 9/16/2019

GCP Oil & Gas

Initial/Previous Registration

7731M1


Transition Type



To Be Removed



Replacement Unit

To Be Removed





Sphere 3 Environmental

GCP Oil and Gas CR

5

Matador Production Company Tom Matthews Facility July, 2020 & Revision #2

GCP-Oil and Gas Form: 10 December 2019 Printed: 7/20/2020

Section 2

Tables _____________________________________________________________________________________________

Insert Excel spreadsheet with applicable tables filled out. If applicable to the facility all tables must be filled out completely.

The unit numbering system must be consistent throughout this Registration

_____________________________________________________________________________________________

6

Matador Production Company Tom Matthews Facility Application Date: July, 2020 Revision #2

8/28/2017FL-

1a/Catalyst

8/28/2017 ENG-1

11/1/2018 N/A

11/1/2018 GEN-1

N/A N/A

N/A HT-1

N/A N/A

N/A HT-2

N/A FL-1b

N/A OT-1

N/A FL-1b

N/A OT-2

N/A FL-1b

N/A OT-3

N/A N/A

N/A OLOAD-1

N/A N/A

N/A SSM-1

N/A N/A

N/A Malf.-1

N/A FL-1b

N/A PWT-1

N/A FL-1b

N/A PWT-2

N/A FL-1b

N/A PWT-3

Power Solutions

International/11L

RICE

Ignition Type

(CI, SI, 4SLB,

2SLB)4

Unit and stack numbering must correspond throughout the application package. Equipment that qualifies for an exemption under

20.2.72.202.B NMAC should be included in Table 2-B Note: Equipment options are not authorized.

Serial #

31000404

40400312

40400312N/A

N/A31000404N/A N/A

0.5

MMBTU/

hr

N/A

400 BBL N/A

Unit

Number1

Controlled by

Unit #

Emissions

vented to

Stack #

Source

Classi-

fication

Code (SCC)

268 HP

ENG-1

Requested

Permitted

Capacity3

(Specify

Units)

1380 HP

268 HPEEIOH80786

5

4SLB

GEN-1 4SRB

20200254

20200253

OT-3 N/A

N/A

Generator-1

HT-2

OT-1 N/AN/A

HT-1

Heater Treater-2

40400312400 BBL

N/A

0.5

MMBTU/

hr

N/A

400 BBL

1380 HP

Oil Tank-2

Source Description

OT-2

Engine-1

Heater Treater-1

Manufact-

urer's Rated

Capacity3

(Specify

Units)

Manufacturer/Make

/Model

Caterpillar/G3516J

(Catalyst:

PowerTherm)

Oil Tank-1

N6W00290

N/A

Date of

Manufacture2

Date of

Construction/

Reconstruction2

0.5

MMBTU/

hr

400 BBL

400 BBL

0.5

MMBTU/

hr

400 BBL

Oil Tank-3 N/A N/A

Table 2-A: Regulated Emission Sources

For Each Piece of Equipment, Check Onc

OLOAD-

1

Oil Truck

Loading-1N/A N/A

4,599,000

gal/yr

459,900

gal/yr40600132 N/A

SSM-1

Shutdown,

Startup and

Maintenance

N/A N/A N/A N/A 31088811 N/A

Malf.-1 Malfunction N/A N/A 10 TPY 10 TPY 31088811 N/A

PWT-3Produced Water

Tank-3N/A N/A 400 BBL 400 BBL 40400315 N/A

400 BBL 40400315

PWT-2Produced Water

Tank-2N/A N/A 400 BBL 400 BBL

N/A

40400315 N/A

PWT-1Produced Water

Tank-1N/A N/A 400 BBL

Form Revision: 6/1/2019 Table 2-L: Page 1 Printed 7/20/2020 10:46 AM

7


RICE

Ignition Type

(CI, SI, 4SLB,

2SLB)4

Serial #Unit

Number1

Controlled by

Unit #

Emissions

vented to

Stack #

Source

Classi-

fication

Code (SCC)

Requested

Permitted

Capacity3

(Specify

Units)

Source Description

Manufact-

urer's Rated

Capacity3

(Specify

Units)

Manufacturer/Make

/Model

Date of

Manufacture2

Date of

Construction/

Reconstruction2


N/A N/A

N/A PWLOAD-1

N/A N/A

N/A FL-1p

N/A N/A

N/A FL-1a

N/A N/A

N/A FL-1b

N/A N/A

N/A FL-1c

N/A N/A

N/A FUG-1

N/A N/A

N/A HR-1

N/A FL-1c

N/A FL-1c

N/A FL-1c

N/A FL-1c1 Unit numbers must correspond to unit numbers in the previous permit unless a complete cross reference table of all units in both permits is provided.

2 Specify dates required to determine regulatory applicability.

3 To properly account for power conversion efficiencies, generator set rated capacity shall be reported as the rated capacity of the engine in horsepower, not the kilowatt capacity of the generator set.

4 "4SLB" means four stroke lean burn engine, "4SRB" means four stroke rich burn engine, "2SLB" means two stroke lean burn engine, "CI" means compression ignition, and "SI" means spark ignition

ICT-1031 N/A310002050.75

Mscf/hr

ICT Energy

Solutions/ICTDUFA

A-10-.2

0.2

MMSCFD

Unpaved Haul

Road-1N/A

N/A31088811N/AN/A N/A

N/AN/A 31088811N/A

156 GPM N/A31000299

TP-1 N/A31000299156 GPM156 GPM

Wilden P8 N/ATP-2

HR-1

FUG-1

FL-1c

156 GPM

Fugitives-1 N/A

Wilden P8 N/A

N/A

Transfer Pump-2

Flare-1: low

pressure,

intermittent;

transfer pumps

Transfer Pump-1

FL-1b

Flare-1: low

pressure,

continuous; oil

and produced

water tanks

ICT Energy

Solutions/ICTDUFA

A-10-.2

ICT-10310.2

MMSCFD

0.64

Mscf/hr31000205 N/A

PWLOA

D-1

Produced Water

Truck Loading-1N/A N/A

24,528,00

0 gal/yr

2,452,800

gal/yr31088811 N/A

FL-1p Flare-1: Pilot

ICT Energy

Solutions/ICTDUFA

A-10-.2

ICT-10310.2

MMSCFD

0.162

Mscf/hr31000205 N/A

FL-1a

Flare-1:high

pressure,

intermittent;

pipeline/product

compressor

downtime

ICT Energy

Solutions/ICTDUFA

A-10-.2

ICT-103110

MMSCFD

116.67

Mscf/hr31000205 N/A


8


N/A N/A N/A N/A

1 Specify date(s) required to determine regulatory applicability.

All 20.2.72 NMAC applications must list Exempted Equipment in this table. If equipment listed on this table is exempt under 20.2.72.202.B.5, include emissions calculations and emissions totals for 202.B.5

"similar functions" units, operations, and activities in Section 5, Calculations. Unit & stack numbering must be consistent throughout the application package.

N/A

Table 2-B: Exempted Equipment (20.2.72 NMAC)

Date of

Manufacture

/Reconstruction1

Date of Installation

/Construction1

Unit Number Source Description Manufacturer

List Specific 20.2.72.202 NMAC Exemption

(e.g. 20.2.72.202.B.5)Max Capacity

Capacity Units

N/A N/A


Model No.

Serial No.


9


FL-1aFlare-1:high pressure, intermittent; pipeline/product compressor

downtimeN/A VOC ENG-1 98%

Manufacturer's

Specifications

FL-1b Flare-1: low pressure, continuous; oil and produced water tanks N/A VOC OT 1-3, PWT 1-3 98%Manufacturer's

Specifications

FL-1c Flare-1: low pressure, intermittent; transfer pumps N/A VOC TP 1-2 98%Manufacturer's

Specifications

N/A Catalyst N/A CO, VOC ENG-1CO (20%), VOC

(25.53%)

Manufacturer's

Specifications

2 Glycol Dehydration Units: Indicate each stream that is being controlled and which unit is controlling each stream (condensables, non-condensables, flash tank, reboiler etc.)

1 List each control device on a separate line. For each control device, list all emission units controlled by the control device.

Table 2-C: Emissions Control Equipment

Control

Equipment

Unit No.

Control Equipment Description Controlled Pollutant(s)Controlling Emissions for Unit

Number(s)1

Unit and stack numbering must correspond throughout the application package. In accordance with 20.2.72.203.A(3) and (8) NMAC, 20.2.70.300.D(5)(b) and (e) NMAC, and 20.2.73.200.B(7) NMAC, the permittee shall

report all control devices and list each pollutant controlled by the control device regardless if the applicant takes credit for the reduction in emissions.

Efficiency

(% Control by

Weight)

Method used to

Estimate

Efficiency

Date

Installed


10


lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr

ENG-1 1.52 6.66 7.61 33.31 4.02 17.59 0.0003 0.0013 0.10 0.44 0.10 0.44 - - - -

GEN-1 0.59 2.59 1.18 5.18 0.41 1.81 0.0001 0.0004 0.06 0.27 0.06 0.27 - - - -

HT-1 0.06 0.27 0.05 0.23 0.003 0.013 - - 0.005 0.022 0.005 0.022 - - - -

HT-2 0.06 0.27 0.05 0.23 0.003 0.013 - - 0.005 0.022 0.005 0.022 - - - -

OT-1 - - - - 15.12 66.22 - - - - - - - - - -

OT-2 - - - - 15.12 66.22 - - - - - - - - - -

OT-3 - - - - 15.12 66.22 - - - - - - - - - -

OLOAD-1 - - - - 74.01 1.33 - - - - - - - - - -

SSM-1 - - - - 405.88 10.55 - - - - - - 0.017 0.00045 - -

PWT-1 - - - - 0.22 0.96 - - - - - - - - - -

PWT-2 - - - - 0.22 0.96 - - - - - - - - - -

PWT-3 - - - - 0.22 0.96 - - - - - - - - - -

PWLOAD-1 - - - - 0.56 0.07 - - - - - - - - - -

FL-1p - - - - 2.26 9.92 - - - - - - 0.0004 0.0015 - -

FL-1a - - - - 1630.53 2678.15 - - - - - - 2.36 3.88 - -

FL-1b - - - - 46.01 201.55 - - - - - - 0.002 0.009 - -

FL-1c - - - - 20.11 0.52 - - - - - - 0.0016 0.0018 - -

FUG-1 - - - - 2.05 9.01 - - - - - - - - - -

HR-1 - - - - - - - - 0.35 0.08 0.04 0.01 - - - -

Malf.-1 - - - - - 10 - - - - - - - - - -

Totals 2.24 9.79 8.89 38.95 2231.87 3142.07 0.0004 0.002 0.5219 0.83 0.2119 0.76 2.38 3.89 0 0

SOx PM101

PM2.51 H2S Lead

1 Condensable Particulate Matter: Include condensable particulate matter emissions for PM10 and PM2.5 if the source is a combustion source.

Table 2-D: Maximum Emissions (Consider federally enforceable controls under normal operating conditions)This table must be filled out

Maximum Federally Enforceable Emissions are the emissions at maximum capacity with only federally enforceable methods of reducing emissions. Calculate the hourly emissions using the

worst case hourly emissions for each pollutant. For each pollutant, calculate the annual emissions as if the facility were operating at maximum facility capacity without pollution controls for

8760 hours per year. Account for federally enforcable controls, such as an NSPS or MACT regulation. Consider federally enforceable controls due to permitting. List Hazardous Air

Pollutants (HAP) in Table 2-I. Unit & stack numbering must be consistent throughout the application package. Fill all cells in this table with the emission numbers or a "-" symbol. A "-"

symbol indicates that emissions of this pollutant are not expected. Numbers shall be expressed to at least 2 decimal points (e.g. 0.41, 1.41, or 1.41E-4).

Unit No.NOx CO VOC


11


lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr

ENG-1 1.52 6.66 6.08 26.65 2.24 9.80 0.0003 0.0013 0.10 0.44 0.10 0.44 - - - -

GEN-1 0.59 2.59 1.18 5.18 0.59 2.58 0.0001 0.0004 0.06 0.27 0.06 0.27 - - - -

HT-1 0.062 0.27 0.052 0.23 0.003 0.013 - - 0.005 0.022 0.005 0.022 - - - -

HT-2 0.062 0.27 0.052 0.23 0.003 0.013 - - 0.005 0.022 0.005 0.022 - - - -

OT-1 - - - - 0.15 0.66 - - - - - - - - - -

OT-2 - - - - 0.15 0.66 - - - - - - - - - -

OT-3 - - - - 0.15 0.66 - - - - - - - - - -

OLOAD-1 - - - - 74.01 1.33 - - - - - - - - - -

SSM-1 - - - - 405.88 10.55 - - - - - - 0.017 0.00045 - -

PWT-1 - - - - - 0.01 - - - - - - - - - -

PWT-2 - - - - - 0.01 - - - - - - - - - -

PWT-3 - - - - - 0.01 - - - - - - - - - -

PWLOAD-1 - - - - 0.56 0.07 - - - - - - - - - -

FL-1p 0.029 0.13 0.06 0.25 0.05 0.2 0.0003 0.0012 - - - - - - - -

FL-1a 20.87 34.27 41.66 68.42 32.61 53.56 0.19 0.31 - - - - 0.047 0.078 - -

FL-1b 0.19 0.82 0.38 1.64 0.92 4.03 0.003 0.011 - - - - - 0.0002 - -

FL-1c 0.13 0.15 0.27 0.29 0.4 0.01 0.001 0.001 - - - - - - - -

FUG-1 - - - - 2.05 9.01 - - - - - - - - - -

HR-1 - - - - - - - - 0.35 0.08 0.04 0.01 - - - -

Malf.-1 - - - - - 10 - - - - - - - - - -

Totals 23.45 45.16 49.73 102.89 519.76 103.17 0.19 0.33 0.52 0.83 0.21 0.76 0.064 0.078 0.00 0.00

VOC SOx

Table 2-E: Requested Allowable EmissionsEnter an allowable emission limit for each piece of equipment with either an uncontrolled emission rate greater than 1 lb/hr or 1 ton per year (tpy) or a controlled emission

rate of any amount. For H2S please represent all emissions even if they are less than 1 lb/hr and 1 tpy. If selecting combustion SSM emissions, enter lb/hr and tpy values.

If selecting up to 10 tpy of Malfunction VOC emissions, enter tpy values. Combustion emissions from malfunction events are not authorized under this permit. Fill all

cells in this table with the emissions in lb/hr and tpy, or a "-" symbol. A “-“ symbol indicates that emissions of this pollutant are not expected. Total the emissions from

all equipment in the Totals row. Add additional rows as necessary. Unit & stack numbering must be consistent throughout the application package. Numbers shall be

expressed to at least 2 decimal points (e.g. 0.41, 1.41, or 1.41E-4

).

Unit No.H2S

1 Condensable Particulate Matter: Include condensable particulate matter emissions for PM10 and PM2.5 if the source is a combustion source.

PM101

PM2.51 LeadNOx CO


12


Height Above Temp. Flow Rate Velocity

Ground (ft) (F) (acfs) (ft/sec)

Engine ENG-1 Vertical 20 832 134.6 280.0 0.50

Generator GEN-1 Vertical 10 1350 23.8 86.9 0.33

Heater

TreaterHT-1 Vertical 30 300 204.8 445.8 0.67

Heater

TreaterHT-2 Vertical 30 300 204.8 445.8 0.67

Flare FL-1p Vertical 46 1500 2.2 94.0 0.19

Flare FL-1a Vertical 50 1500 446.7 401.0 0.64

Flare FL-1b Vertical 46.33 1500 2.2 94.0 0.19

Flare FL-1c Vertical 46.33 1500 2.2 94.0 0.19

Unit and stack numbering must correspond throughout the application package. Include the stack exit conditions for each unit that emits from a stack, including blowdown venting parameters and

tank emissions.

Table 2-H: Stack Exit Conditions

Orientation

(H-Horizontal

V=Vertical)

Serving Unit Number(s) from

Table 2-A

Stack Type

(Engine,

Turbine,

Flare, ECD,

or Thermal

Oxidizer

Etc.)

Inside Diameter (ft)


13


lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr lb/hr ton/yr

1 ENG-1 - 0.1 - - - - - - - - - - - - - -

2 GEN-1 0.1 0.4 - - - - - - - - - - - - 0.1 0.4

3 HT-1 - - - - - - - - - - - - - - - -

4 HT-2 - - - - - - - - - - - - - - - -

5 OT-1 - - - - - - - - - - - - - - - -

6 OT-2 - - - - - - - - - - - - - - - -

7 OT-3 - - - - - - - - - - - - - - - -

8 OLOAD-1 0.5 - 0.1 - 0.1 - - - 0.1 - - - 0.2 - - -

9 SSM-1 10.7 0.3 0.4 - - - - - - - - - - - - -

10 PWT-1 - - - - - - - - - - - - - - - -

11 PWT-2 - - - - - - - - - - - - - - - -

12 PWT-3 - - - - - - - - - - - - - - - -

13PWLOAD-

1- - - - - - - - - - - - - - - -

14 FL-1p - - - - - - - - - - - - - - - -

15 FL-1a 0.2 0.3 - - 0.1 0.1 - - 0.1 0.1 - - 0.1 0.1 - -

16 FL-1b - - - - - - - - - - - - - - - -

17 FL-1c - - - - - - - - - - - - - - - -

18 FUG-1 0.1 0.3 - - - - - - - - - - - - - -

19 HR-1 - - - - - - - - - - - - - - - -

20 Malf.-1 - 0.1 - - - - - - - - - - - - -

Totals: 11.61 1.48 0.52 0.09 0.18 0.13 0.05 0.03 0.16 0.12 - - 0.24 0.18 0.08 0.36

Toluene √

HAP

E-Benzene √

HAP Stack No. Unit No.(s)

Total HAPsBenzene √

HAP

Provide Pollutant

HAP

HAP In the table below, report the potential emission rate for each HAP from each regulated emission unit listed in Table 1, only if the entire facility emits the HAP. For each such emission unit, HAP

shall be reported to the nearest 0.1 tpy. Each facility-wide Individual HAP total and the facility-wide Total HAP shall be the sum of all HAP sources calculated to the nearest 0.1 ton per year. Use the

HAP nomenclature as it appears in Section 112 (b) of the 1990 CAAA. Include tank-flashing emissions estimates of HAP in this table. For each HAP listed, fill all cells in this table with the emission

numbers or a "-" symbol. A “-” symbol indicates that emissions of this pollutant are not expected, or the pollutant is emitted in a quantity less than the threshold amounts described above. Add additional

rows as necessary.

Table 2-I: Emission Rates for HAPs

224Trimethlyp

√ HAP

Formaldehyde

√ HAP

Xylenes √

HAP

n-Hexane √

HAP


14


ENG-1 Field Gas Field Gas 0.02% N/A 1296 68.1

HT-1 Field Gas Field Gas


Roof Shell

OT-1 N/A Crude OilVertical - Fixed

Roof (FX)N/A 400 3.6576 3.048 Dark Green Dark Green 599.65 1,533,000 91.25





PWT-1 N/A Produced WaterVertical - Fixed






Table 2-L: Tank Data

Tank No.Date

Installed

Diameter

(M)

Include appropriate tank-flashing modeling input data. Unit and stack numbering must correspond throughout the application package.

Capacity

(bbl)

Separator

Pressure

(psia)

Annual

Throughput (gal/yr)

Turn-

overs (per year)

Materials Stored

Vapor

Space

(M)

Color Roof Type Seal Type


16



Section 3 Registration Summary

______________________________________________________________________________________________________

The Registration Summary: Provide information about the registration submittal. The Registration Summary shall include a

brief description of the facility and its process. In case of a modification to a facility, please describe the proposed changes.

______________________________________________________________________________________________________

Specify Facility Type: Check the appropriate box below:

Production Site

Tank Battery

Compressor Station

Natural Gas Plant

Other, please specify:______________

Registration Summary:

This application, as well as all related materials, presents all necessary information for equipment onsite and operations carried

out to produce oil, natural gas, and produced water from wellstream fluids extracted from any associated wells. Included

materials summarize updated calculated emissions in accordance with equipment and process flow including a revision to

compression. State and federally-enforceable regulations applicable to this facility and/or equipment, have also been included.

Written description of the routine operations of the facility:

The full well stream enters the Tom Matthews Facility and passes through inlet separation. The natural gas from the separators

is sent to a compressor to increase pressure (ENG-1). Once pressure has been increased, gas is routed to a sales pipeline for

offsite processing. When the pipeline or compressor are down, gas is redirected to the flare for control (FL-1a). Produced water

is directed to onsite storage tanks (PWT 1-3) until they can be transported offsite. Remaining fluids are piped through

additional separation (HT 1-2) where separated oil is directed to storage tanks (OT 1-3). Produced water is directed to storage

tanks and then piped offsite to a saltwater disposal facility. When the pipeline is down, liquids are loaded (PWLOAD-1) and

trucked offsite (HR-1). Oil is directed through a LACT metering unit to an offsite sales pipeline. When the pipeline is down,

liquids are loaded (OLOAD-1) and trucked offsite. Vapor produced in the storage tanks is directed to the flare (FL-1b) for

combustion. Electricity is provided by an onsite generator (GEN-1). Transfer pumps move liquids around the facility.

Pneumatic pump exhaust is vented to flare (FL-1c). Remaining transfer pumps are electric. Additional streams directed to flare

include a pilot (FL-1p).

Changes reflected in this application include:

• Removal of Engine 2

• Replacement of Generator-1

• Removal of Vapor Recovery Unit-1

• Addition of two diaphragm pumps

• Update to production volume

Routine or predictable emissions during Startup, Shutdown and Maintenance (SSM):

Startup, shutdown and maintenance (SSM) activities that may occur at this facility consist of the following:

• Compressor Blowdowns

• Miscellaneous activities associated with the maintenance and upkeep of an oil and production facility

• Painting and Blasting

Compressor blowdowns occur when an engine driver or compressor is down for maintenance and the compressor cannot be

allowed to retain gas and is therefore released.

Miscellaneous oil and gas maintenance activities include (but are not limited to) engine oil and filter changes, changing engine

rod packing, changing engine seals, use of aerosol lubricants, pneumatic controls and instrumentation and calibration. All the

above listed activities result in the release of VOC’s to the atmosphere.

Painting and blasting activities also occur during maintenance of equipment and storage tanks. Painted areas are “blasted” with

17



abrasive media to remove coatings. Exposed areas are painted over. Blasting releases particulate emissions as well as VOC’s to

the atmosphere.

Malfunction Emissions (M):

The permit application is authorizing Malfunction emissions separate from SSM emissions.

Allowable Operations: Check the appropriate box below:

Facility operates continuously (8760 hours per year)

The following regulated equipment will operate less than 8760 hours per year. Add additional rows as necessary. These

units are subject to Condition A108.C of the Permit.

Table A – Equipment Operating Less Than 8760 hours per year

Unit # Requested Annual

Operating Hours

Verification of Compliance with Stack Parameter Requirements:

Please use the Stack Calculator and Stack Requirements Explained Guidance on our website: All of the verification

information below is required to be filled out.

www.env.nm.gov/air-quality/air-quality-oil-and-gas-gcp-application-forms/

Check the box for each type of equipment at this facility:

Engine(s)

Turbine(s)

Flares(s)

Enclosed Combustion Device (s)

Heater(s)

Reboiler(s)

For each type of equipment checked above, complete the applicable section below.

Engines

1. Calculate the pound per hour (lb/hr) NOx emission rate according to GCP O&G Condition A202.I Step 1 on page

15 of the GCP O&G. Enter this value in the top row of the table below.

2. Based on the calculated facility total NOx emission rate, determine the minimum stack parameter requirements for

engines and heaters from Table 1: Engines (page 17) of the GCP O&G and enter the minimum parameters from

Table 1 (page 17) of the GCP O&G in the bottom row of the table below.

3. Enter the stack parameters from each engine and heater in the blank rows of the table below. Add rows as

necessary.

Table B: Engine/Generator/Heater/Reboiler Stack Parameter Verification:

Calculated Facility Total NOx Emission Rate: _2.23__lb/hr

Engine/Generator/Heater/Reboiler

Unit Number

Height (ft) Temperature (⁰F) Velocity (ft/s) Diameter (ft)

ENG-1 20 832 280.03 0.5

GEN-1 10 1350 86.85 0.33

HT-1 30 300 445.75 0.67

HT-2 30 300 445.75 0.67

18

http://www.env.nm.gov/air-quality/air-quality-oil-and-gas-gcp-application-forms/



Equipment

Name

NOx Rate

(lb/hr)

SO2 Rate

(lb/hr)Height (ft)

Diameter

(ft)

Velocity

(ft/s)

Temp

(deg. F)

Height

Min (ft)

Diameter

Min (ft)

Velocity

Min (ft/s)

Temp Min

(deg. F)

Height Diff

(ft)

Diameter

Diff (ft)

Velocity

Diff (ft/s)

Temp Diff

(deg. F)

ENG-1 1.52 0.0013 20 0.5 280.03 832 8.2 0.3 49.2 571 11.8 0.2 230.83 261

GEN-1 0.59 0.0004 10 0.33 86.85 1350 8.2 0.3 49.2 571 1.8 0.03 37.65 779

HT-1 0.062 0 30 0.67 445.75 300 0 0 0 0 30 0.67 445.75 300

HT-2 0.062 0 30 0.67 445.75 300 0 0 0 0 30 0.67 445.75 300

FL-1p 0.029 0.0003 46.33 0.19 94 1500 6.6 0 0 0 39.73 0.19 94 1500

FL-1a 20.87 0.19 49.5 0.64 401 1500 6.6 0 0 0 42.9 0.64 401 1500

FL-1b 0.19 0.0026 46.33 0.19 94 1500 6.6 0 0 0 39.73 0.19 94 1500

FL-1c 0.13 0.0012 46.33 0.19 94 1500 6.6 0 0 0 39.73 0.19 94 1500

Calculated Facility Total NOx Emission Rate: _2.23__lb/hr

Engine/Generator/Heater/Reboiler

Unit Number


Table 1 Minimum Parameters:

For verification, list the minimum

parameters based on the NOx lb/hr

emission rate from the GCP O&G

Table 1.

8.2 571 49.2 0.3

4. Do all engines and heaters comply with the minimum stack parameters from Table 1 (page 17) of the GCP O&G?

Yes. Skip step 5 below.

No. Go to step 5 below.

5. For engines and heaters that do not comply with the minimum stack parameters in Table 1 of the GCP O&G,

explain and demonstrate in detail how the engines and heaters will be authorized according to the steps on page

16 of the GCP O&G or Condition A203.C of the GCP O&G. Show all calculations.

The above table demonstrates facility compliance as it pertains to the GCP Oil and Gas stack height requirements. The left side

of the table presents the actual values of the combustible sources at this facility while the middle in bolded outline, shows the

requirements that each piece of equipment must meet. The right side of the table outlined in red, represents the overages from

the equipment able to compensate for shortages presented by the other devices onsite. According to the GCP Oil and Gas

regulations; A.202 (I) Engine Stack Parameter Requirements, other pieces of equipment onsite may compensate for any

individual that does not meet minimum standards for height, diameter, velocity or temperature. Due to the compensation from

other devices onsite, this facility is compliant with GCP Oil and Gas standards. Additionally, the heater treater source does not

meet the minimum stack parameter requirements of the GCP Oil and Gas permit. However, an exception to these standards is

stated in A203.C in which due to the size, is considered a small heater and therefore is not subject to these requirements.

Turbines

1. Calculate the pound per hour (lb/hr) NOx emission rate according to GCP O&G Condition A202.I Step 1 on page

17 of the GCP O&G. Enter this value in the top row of the table below.

2. Based on the calculated facility total NOx emission rate, determine the minimum stack parameter requirements for

turbines and heaters from Table 2: Turbines (page 18) of the GCP O&G. Enter the minimum parameters from

Table 2 (page 18) of the GCP O&G in the bottom row of the table below.

3. Enter the stack parameters from each turbine and heater in the blank rows of the table below. Add rows as

necessary.

Table C: Turbine/Heater/Reboiler Stack Parameter Verification:

Calculated Facility Total NOx Emission Rate: _____lb/hr

Turbine/Heater/Reboiler

Unit Number


Table 2 Minimum

Parameters: For

verification, list the

19



Calculated Facility Total NOx Emission Rate: _____lb/hr

Turbine/Heater/Reboiler

Unit Number


minimum parameters

based on the NOx lb/hr

emission rate from the

GCP O&G Table 2.

4. Do all turbines and heaters comply with the minimum stack parameters from Table 2 (page 18) of the GCP

O&G?



5. For turbines and heaters that do not comply with the minimum stack parameters in Table 2 of the GCP O&G,

explain and demonstrate in detail how the turbines and heaters will be authorized according to the steps on page

18 of the GCP O&G or Condition A203.C of the GCP O&G. Show all calculations.

Flares

1. Enter SO2 emission rates (lb/hr) for each flare in the second column of the table below.

2. Based on the SO2 emission rates, determine the minimum stack height requirements for flares from Table 3 (page 26)

of the GCP O&G and enter the minimum stack height requirements for flares from Table 3 (page 26) of the GCP O&G

in the last column of the table below.

3. Enter the stack height of each flare in the third column of the table below. Add rows as necessary.

Table D: Flare Stack Height Parameter Verification:

Flare Unit Number SO2 Emission Rate

(lb/hr)

Height (ft) Table 3 Minimum

Stack Height: For

verification, list the

minimum height

parameters based on

the SO2 emission rate

from the GCP O&G

Table 3.

FL-1p 0.0003 46.33 6.6

FL-1a 0.19 49.5 6.6

FL-1b 0.0026 46.33 6.6

FL-1c 0.0012 46.33 6.6

4. Do all flares comply with minimum stack height requirements?

Yes

No

5. Does the flare gas contain 6% H2S or less by volume (pre-combustion)?



6. Explain in detail how assist gas will be added to reduce the gas composition to 6% H2S or less by volume.

20



Enclosed Combustion Device(s) (ECD):

According to GCP O&G Condition A208.A, the facility must meet one of the following options if an ECD is installed at the

facility:

Option 1:

1. Will the ECD(s) meet the SO2 emission limit of 0.7 lb/hr and operate with a velocity of at least one (1) foot per

second?

Yes. Skip Option 2 below.

No. Go to Option 2 below.

Option 2:

2. Will the ECD(s) meet the SO2 emission limit of 0.9 lb/hr and operate with a velocity of at least two (2) feet per

second?

Yes

No

21



Section 4

Process Flow Sheet _____________________________________________________________________________________________

Attach a process flow sheet indicating all individual equipment, all emission points, and types of control applied to those

points. All units must be labeled, and the unit numbering system must be consistent throughout this Registration. Identify all

sources of emissions with a vertical arrow. Label each of the different material streams (e.g. crude oil, gas, water). The

process flow sheet must be a legible size.

__________________________________________________________________________________________________

22

7/15/20207/15/2020

Prepared by: Sphere 3 Environmental, Inc.

Process Flow Diagram for the Tom Matthews Facility

Prepared for: Matador Production Company.

Primary Wells

Fugitive Sources(FUG-1)

Startup, Shutdown and Maintenance(SSM-1, Malf.-1)

Fluids SeparatorHeater Treater

(HT-1, HT-2)Oil Storage Tanks(OT-1, OT-2, OT-3)

Oil Truck Loadout(OLOAD-1)

Produced Water Storage Tanks

(PWT-1, PWT-2, PWT-3)

Produced Water Loadout

(PWLOAD-1)

Compression(ENG-1)

Offsite Gas SalesGas

Gas

Oil

Produced Water

Oil Oil

ProducedWater

Gas

PW Tank Vapors(FL-1b)

Oil Tank Vapors(FL-1b)

Flare(FL-1p)

Unpaved Haul Road

(HR-1)

ProducedWater

SWD Pipeline

LACT(To Oil Pipeline)

HP Downtime(FL-1a)

Generator(GEN-1)

Transfer Pumps(TP 1-2)

Exhaust(FL-1c)

23


Form Revision: 10 December 2019 Printed: 7/20/2020

Section 5

Emissions Calculation Forms _____________________________________________________________________________________________

The Department has developed the Air Emissions Calculation Tool (AECT), which is required to be used in the GCP-Oil and

Gas Registration. If the AECT, for a piece of equipment is under development, provide alternate calculations. Do not include

alternative calculations unless there is an issue being resolved with the AECT. This will delay review of the application.

The AECT and this Registration Form may be updated as needed.

Tank Emissions Calculations: Provide the method used to estimate tank-flashing emissions, the input and output summary

from simulation models and software, all calculations, documentation of any assumptions used, descriptions of sampling

methods and conditions, copies of any lab sample analysis. If Pro-Max or Hysis is used, all relevant input parameters shall be

reported, including separator pressure, gas throughput, and all other relevant parameters necessary for flashing calculation. The

inputs must match the gas analyses information submitted. Inputs that don’t match may be grounds for denial of the

application submittal.

SSM Calculations: In this Section, provide emissions calculations for Startup, Shutdown, and Routine Maintenance (SSM)

emissions listed in the Table 2, and the rational for why the others are reported as zero (or left blank).

Control Devices: Report all control devices and list each pollutant controlled by the control device. Indicate in this section if

you chose to not take credit for the reduction in emission rates. Only uncontrolled emission rates can be considered to

determine applicability unless the state or federal acts require the control. This information is necessary to determine if

federally enforceable conditions are necessary for the control device, and if the control device produces its own regulated

pollutants or increases emission rates of other pollutants.

Calculation Details: The AECT is required for all emission calculations. If the AECT is not functioning, alternative

calculations may be submitted only for the portions of the AECT with issues being resolved. Utilize this section to explain in

detail, on an equipment-by-equipment basis, why alternative calculations are necessary.

Explain here: HAPs, Fugitives, Transfer Pumps. Complete calculations not provided by AECT.

_____________________________________________________________________________________________

Equipment Forms Submitted in this Section (add additional rows as necessary):

Equipment Type Quantity

Check Box

to Indicate

Units that

are

Controlled

Enter Control Device Type

and Pollutant Controlled

Engine 1 Catalyst; VOC, CO

Turbine

Tanks 6 FL-1b; VOC

Generator 1

VRU

VRT

ULPS

Glycol Dehydrator

Flare 1 TP 1-2, OT 1-3, PWT 1-3; VOC

Amine Unit

Cryogenic Unit

Fugitive Emissions 1

Heater 2

Truck Loading 2

Enclosed Combustion

Device (ECD)

Thermal Oxidizer (TO)

Other

24



Other

For each scenario below, if there are more than one emissions unit, control device, or gas combustion scenario. Please

copy and paste each applicable section and label the unit number(s) if the scenarios vary.

Vapor Recovery Tower, Ultra Low-Pressure Separator, or Flash Tower Located Upstream of Storage Vessels: If the

facility contains one of the following units located upstream of the storage vessels and is used to flash and capture flashing

emissions, check the appropriate box.

Unit number:

Vapor Recovery Tower and VRU Compressor

ULPS and VRU Compressor

Flash Tower and VRU Compressor

Vapor Recovery Unit (VRU) located upstream of Storage Vessels: Check the box below if the facility is using a VRU to

capture flashing emissions prior to any storage vessels to limit the PTE of the storage vessels to below applicability thresholds

of NSPS OOOO or NSPS OOOOa. A process vs control determination should be prepared for this type of VRU application.

Unit number:

VRU capturing emissions prior to any storage vessel and routing directly to the sales pipeline

Vapor Recovery Unit (VRU) attached to Storage Vessels: Check the box below if this facility is using a VRU to reduce

storage vessel emissions to limit the PTE to below NSPS OOOO or NSPS OOOOa applicability thresholds:

Unit number:

VRU controlling Storage Vessel emissions and the facility is subject to the requirements under NSPS OOOO, 40 CFR

60.5411

VRU controlling Storage Vessel emissions and the facility is subject to the requirements under NSPS OOOOa, 40 CFR

60.5411a

Gas Combustion Scenarios: Read through the scenarios below and check the boxes next to any appropriate facility operating

scenarios. Flares shall assume a destruction efficiency of 95%, unless the facility is subject to requirements for flares under 40

CFR 60.18, or a higher destruction efficiency (up to 98%) is supported by a manufacturer specification sheet (MSS) for that unit.

If so, include the MSS.

A flare, vapor combustion unit (VCU), enclosed combustion device (ECD), thermal oxidizer (TO):

Unit number: FL-1

Controls storage vessels in accordance with 40 CFR 60, Subpart OOOO or OOOOa.

Provides a federally enforceable control for the storage vessels to limit the PTE to below applicability thresholds of 40

CFR 60, Subpart OOOO or OOOOa.

Controls the glycol dehydrator

Controls the amine unit

Controls truck loading

Operates only during maintenance events, such as VRU downtime, check one below:

The emissions during VRU downtime are represented as uncontrolled VOC emissions from the compressor

The combustion emissions during VRU downtime are represented as controlled emissions from the combustion

device

Controls the facility during plant turnaround

Amine Unit: Provide the following information for each amine unit.

Design Capacity in MMscf/day

Rich Amine Flowrate in gal/min

Lean Amine Flowrate in gal/min

Mole Loading H2S

Sour Gas Input in MMscf/day

25



Glycol Dehydration Unit(s): Provide the following information for each glycol dehydration unit:

Please include an extended gas analysis in Section 6 of this application.

Unit # Glycol Pump Circulation Rate

Voluntary Monitoring in Accordance with §40 CFR 60.5416(a): Check the box(s) to implement a program that meets the

requirements of 40 CFR 60.5416(a). This monitoring program will be conducted in lieu of the monitoring requirements

established in the GCP-Oil and Gas for individual equipment. Ceasing to implement this alternative monitoring must be

reported in an updated Registration Form to the Department.

Condition A205.B Control Device Options, Requirements, and Inspections for Tanks

Condition A206.B Truck Loading Control Device Inspection

Condition A206.C Vapor Balancing During Truck Loading

Condition A209.A Vapor Recovery Unit or Department-approved Equivalent

Condition A210.B Amine Unit Control Device Inspection

Fugitive H2S Screening Threshold and Monitoring in accordance with Condition A212: Check the box that applies.

Condition A212.A does not apply because the facility is below the fugitive H2S screening threshold in Condition A212, or

Condition A212.A applies. Because the facility is above the fugitive H2S screening threshold in Condition A212, or the

facility is voluntarily complying with Condition A212.A, and Condition A212.A applies

26

Company Name: Matador Production Company Permit No.: 7731M1

Site Name: Tom Matthews Facility Date:

Facility Name (FIN): TP 1-2

Emission Calculations for Gas-Operated Circulation Pump

Source: Based on Gas Throughput (Usage)

[For Estimating Emissions from Pneumatic Liquid Pumps Powered by Gas Pressure]

INPUTS:

150 LiqFlow

100 NG

50 NG

15

750.0 Q

379

21.51 MWng

0.236 NGvoc

0.006 NGhap

0.000 NGH2S

Propane Butane Pentane

0.118 0.061 0.024

Hexane TMP B T E X

5.13E-03 0.00E+00 2.50E-04 4.70E-04 5.00E-05 3.50E-04

Note: 1) Gas pressure supplied by: (sweet) field gas

2) Hourly emissions based on a maximum run time of 15 minutes per hour.

3) Annual emissions based on average run time of one hour per week.

TOTAL EMISSIONS:

Emissions = Q * 1/379 scf/lb-mole * MWng

lbs/hr TPY

TOTAL = 42.566 4.427 TOTAL Emissions from Transfer Pump

VOC EMISSIONS:

VOC = TOTAL * NGvoc

lbs/hr TPY

VOC = 10.057 1.046 VOC Emissions from Transfer Pump

TP 1-2 20.11412 2.0918685

0.5229671 (15min pump run time)

Mscf/hr MMscf/yr MMscf/yr

0.75 6.57 1.6425 (15min pump run time)

SPECIATED VOC = TOTAL * Frac. of Speciated VOC in the Natural Gas

VOC lbs/hr TPY

Propane 5.019 0.522

Butane 2.611 0.272

Pentane 1.013 0.105 VOC Emissions from Transfer Pump

Molecular Weight of Natural Gas (lb/lb-mole)

29-Jun-20

Pump Manufacturer Wilden

Pump Model No. P8

Design Maximum Liquid Flow Rate (gallons / minute)

Design Maximum Gas Consumption (scfm)

Average Gas Consumption (scfm)

Maximum Hourly Pump Run Time (minutes)

Maximum Gas Usage (scf/hr) (Assumption )

Volume of 1 lb-mole of gas at Standard Conditions (scf/lb-mole)

Fraction Speciated HAP of Natural Gas (lbx/lbgas)

Fraction VOC (C3+) of Natural Gas (lbx/lbgas)

Fraction Total HAPs of Natural Gas (lbx/lbgas)

Fraction Total H2S of Natural Gas (lbx/lbgas)

Speciated VOCs

Fraction Speciated VOC of Natural Gas (lbx/lbgas)

Speciated HAPs

Transfer Pump TM-Pumps.xlsx

6/29/2020

55

HAP EMISSIONS:

Total HAPs = TOTAL * NGhap

lbs/hr TPY

TOT_HAPs = 0.266 0.028 HAP Emissions from Transfer Pump

SPECIATED HAP = TOTAL * Frac. of Speciated HAP in the Natural Gas

HAP lbs/hr TPY

Hexane 0.218 0.023

TMP 0.000 0.000

B 0.011 0.001

T 0.020 0.002

E 0.002 0.000

X 0.015 0.002 HAP Emissions from Transfer Pump

H2S EMISSIONS:

Total H2S = TOTAL * NGH2S

lbs/hr TPY

H2S = 0.000 0.000 H 2 S Emissions from Transfer Pump

Transfer Pump TM-Pumps.xlsx

6/29/2020

56

Company Name: Matador Production Company Permit No.:


Facility Name (FIN): Flare (FL-1) Value: Field Gas Sulfur Content (S grains/100 scf)

BASES:

379 StdMV

32.066 MWS

7000 CFgr

INPUTS:

1 2 3

0.0025

OUTPUTS:

1 2 3

1.48 0.00 0.00

Facility Name (FIN): Haul Road (HR-1) Value: Round-Trips Determination (#)

BASES:

180 TrkVolOil

120 TrkVolPW

INPUTS:

Oil PW

300 1600

10% 10%

OUTPUTS:

Oil PW Total

0.07 0.56 1

61 487 548

Products

Number of Haul Road Round-trips/hour

Number of Haul Road Round-trips/year

Products

Oil Truck Capacity (bbl)

Produced Water Truck Capacity (bbl)

Production (bbl/day)

% of Time Product Removed by Truck

Molecular Weight of Sulfur (lb/lb-mole)

Flare - Gas Stream #

H2S Concentration (mole %)

Field Gas Sulfur Content (S grains/100 scf)

Flare - Gas Stream #

Conversion Factor (grains/lb)

7731M1

29-Jun-20

AECT Supplemental Calculations

Calculations to Determine Data Inputs for Various AECT Calculation Sheets

Volume of 1 lb-mole of gas at Standard Conditions (scf/lb-mole)

Flare & Haul Road

TM_Supp.xlsx

6/29/2020

57

Company Name: Matador Production Company Date: 7/16/2020

Site Name: Tom Matthews Facility

INPUTS:

VOCs (tpy) Number ComponentW&B Gas

wt %W&B fraction

Normalized W&B

Fraction

9.80 1 H2S 0.002065377 2.06538E-05

2.22 2 O2 0 0

0.01 3 CO2 0.082174979 0.00082175

0.01 4 N2 0.004457785 4.45779E-05

0.66 5 C1 3.33117776 0.033311778

0.66 6 C2 30.1148444 0.301148444

0.66 7 C3 32.3096543 0.323096543 0.486117959

1.33 8 i-C4 5.521643956 0.05521644 0.083076416

0.01 9 n-C4 13.41748121 0.134174812 0.201873982

0.01 10 i-C5 3.683461785 0.036834618 0.055419873

0.01 11 n-C5 4.202987039 0.04202987 0.063236439

0.07 12 C6 3.420251781 0.034202518 0.051459722

0.20 13 Benzene 0.054540119 0.000545401 0.000820589

53.56 14 Toluene 0.10557694 0.001055769 0.001588468

4.03 15 E-Benzene 0.027439441 0.000274394 0.000412843

0.01 16 Xylenes 0.09411312 0.000941131 0.001415988

0.00 17 2&3 Methylpentane 0 0 0

10.00 18 224Trimethylp 0.144764057 0.001447641 0.002178061

19 C7 2.186676302 0.021866763 0.032899845

20 C8 1.09689921 0.010968992 0.016503501

21 C9 0.194250412 0.001942504 0.002922613

22 C10+ 0.004898554 4.89855E-05 7.37017E-05

23 Pseudo Comp5 0 0 0

0.664646382

Hazardous Air Pollutants - Determination of Major Source

Pollutant Total (tpy) 0.18 Pollutant Total (lb/hr) 0.24

Benzene 0.07 0.53 Benzene 0.09 0.72

Toluene 0.13 Toluene 0.18 Formaldehyde 0.0821

E-Benzene 0.03 NO E-Benzene 0.05 SSM-1 10.736Xylenes 0.12 Formaldehyde 0.3596 Xylenes 0.16 FUG-1 0.07

n-Hexane 0.00 SSM-1 0.279 n-Hexane 0.00 Total HAPs (pph) 11.61

224Trimethylp 0.18 FUG-1 0.31 224Trimethylp 0.24

FUG-1 Benzene 0.01 Total HAPs (tpy) 1.48 FUG-1 Benzene 0.002

SSM-1 Benzene 0.01117 SSM-1 Benzene 0.42946

Total Benzene 0.09 Total Benzene 0.52

Hazardous Air Pollutants - Emission Source: ENG-1

Pollutant lb/hr Total HAPS Max HAPs Pollutant tpy Total HAPs Max HAPS

H2S 0.00 lb/hr lb/hr H2S 0.00 tpy tpy

Propane 1.09 0.01 0.00 Propane 4.76 0.06 0.02

Butanes 0.64 Formaldehyde 0 Butanes 2.79 Formaldehyde 0

Pentanes 0.27 Total: 0.01 Pentanes 1.16 Total: 0.06

Hexanes 0.12 Hexanes 0.50

Benzene 0.00 Benzene 0.01

Toluene 0.00 Toluene 0.02

E-Benzene 0.00 E-Benzene 0.00

Xylenes 0.00 Xylenes 0.01

n-Hexane 0.00 n-Hexane 0.00

224Trimethylp 0.00 224Trimethylp 0.02

Psuedo Comp1 0.07 Psuedo Comp1 0.32





Total VOCS 2.24 Total VOCS 9.80

Hazardous Air Pollutants - Emission Source: GEN-1



Propane 0.25 0.00 0.00 Propane 1.08 0.01 0.00

Butanes 0.14 Formaldehyde 0.0821 Butanes 0.63 Formaldehyde 0.3596

Pentanes 0.06 Total: 0.09 Pentanes 0.26 Total: 0.37














Major Source of HAPs?

Largest HAP (tpy)

Total HAPs (tpy)

Malf.-1 0.00

FL-1b 0.92

FL-1c 0.40

HR-1 0.00

PWLOAD-1 0.56

FL-1p 0.05

FL-1a 32.61

PWT-1 0.00

PWT-2 0.00

PWT-3 0.00

Emission Estimations for HAPS

Emission Source VOCs (lb/hr)

ENG-1 2.24

Largest HAP (lb/hr)

Total HAPs (lb/hr)

GEN-1 0.51

HT-1 0.00

HT-2 0.00

OT-1 0.15

OT-2 0.15

OT-3 0.15

OLOAD-1 74.01

58

Hazardous Air Pollutants - Emission Source: HT-1



Propane 0.00 0.00 0.00 Propane 0.01 0.00 0.00

Butanes 0.00 Butanes 0.00

Pentanes 0.00 Pentanes 0.00














Hazardous Air Pollutants - Emission Source: HT-2



Propane 0.00 0.00 0.00 Propane 0.01 0.00 0.00
















Hazardous Air Pollutants - Emission Source: OT-1



Propane 0.07 0.00 0.00 Propane 0.32 0.00 0.00



















Propane 0.07 0.00 0.00 Propane 0.32 0.00 0.00
















59




Propane 0.07 0.00 0.00 Propane 0.32 0.00 0.00
















Hazardous Air Pollutants - Emission Source: OLOAD-1



Propane 35.98 0.47 0.16 Propane 0.65 0.01 0.00
















Hazardous Air Pollutants - Emission Source: PWT-1



Propane 0.00 0.00 0.00 Propane 0.00 0.00 0.00



















Propane 0.00 0.00 0.00 Propane 0.00 0.00 0.00
















60




Propane 0.00 0.00 0.00 Propane 0.00 0.00 0.00
















Hazardous Air Pollutants - Emission Source: PWLOAD-1



Propane 0.27 0.00 0.00 Propane 0.03 0.00 0.00
















Hazardous Air Pollutants - Emission Source: FL-1p



Propane 0.02 0.00 0.00 Propane 0.10 0.00 0.00
















Hazardous Air Pollutants - Emission Source: FL-1a



Propane 15.85 0.21 0.07 Propane 26.04 0.34 0.12
















61

Hazardous Air Pollutants - Emission Source: FL-1b



Propane 0.45 0.01 0.00 Propane 1.96 0.03 0.01
















Hazardous Air Pollutants - Emission Source: FL-1c



Propane 0.19 0.00 0.00 Propane 0.00 0.00 0.00
















Hazardous Air Pollutants - Emission Source: HR-1



Propane 0.00 0.00 0.00 Propane 0.00 0.00 0.00
















Hazardous Air Pollutants - Emission Source: Malf.-1



Propane 0.00 0.00 0.00 Propane 4.86 0.06 0.02
















62

Company Name: Matador Production Company Permit No.:


Facility Name (FIN): FUG-1

7731M1

29-Jun-20

Source: EPA "Protocol for Equipment Leak Emission Estimates," November 1995, EPA-453/R-95-017

Fugitive Emission Estimates for Oil and Gas Production Sites

[For Estimating Fugitive Emissions from Oil & Gas Production Equipment]

OUTPUTS:

Component - Service

Fugitive

Emission

Factor

(lb/hr)/comp

Component

Counts

Valves - Gas 0.009921 191

Valves - Heavy Oil 0.0000185 0

Valves - Light Oil 0.005512 83

Valves - Water/Oil 0.000216 75

Pump Seals - Gas 0.005291 0

Pump Seals - Heavy Oil 0.028660 0

Pump Seals - Light Oil 0.028660 1

Pump Seals - Water/Oil 0.000053 0

Connectors - Gas 0.000441 506

Connectors - Heavy Oil 0.0000165 12

Connectors - Light Oil 0.000463 237

Connectors - Water/Oil 0.000243 195

Flanges - Gas 0.000860 337

Flanges - Heavy Oil 0.00000086 8

Flanges - Light Oil 0.000243 158

Flanges - Water/Oil 0.0000064 130

Open-ended Lines - Gas 0.004410 35

Open-ended Lines - Heavy Oil 0.0003090 0

Open-ended Lines - Light Oil 0.003087 10

Open-ended Lines - Water/Oil 0.000551 3

Other* - Gas 0.019401 88

Other* - Heavy Oil 0.0000706 0

Other* - Light Oil 0.016535 12

Other* - Water/Oil 0.030865 3

Notes:

1) All factors are in units of (lb/hr)/component.

2) Factors give total organic compound (TOC) emission rate. Multiply by the weight percent of non-methane, non-ethane organics to get the VOC emission rate.

3) Component counts estimated based on typical setups for equipment on site.

4) Assumed H2S concentration in the liquid is the same as the H2S concentration in the gas.

* "Other" includes compressors, diaphragms, dump arms, hatches, instruments, meters, polished rods, process drains, relief valves, and vents.

Fugitive Component Counts

TM_FUG.xlsx

6/29/2020

63



Section 6

Information Used to Determine Emissions _____________________________________________________________________________________________

Check the box for each type of information submitted. This documentation is required. If applicable to the facility.

Failure to include applicable supporting documentation may result in application denial.

Specifications for control equipment, including control efficiency specifications and sufficient engineering data for verification of control equipment operation, including design drawings, test reports, and design parameters that affect normal

operation.

Engine or Generator Manufacturer specifications

Catalyst Manufacturer specifications (If a catalyst is being utilized to reduce emissions, the catalyst manufacturer

emission factors must be used in all emission calculations. A 25% safety factor may be applied to each pollutant.

NSPS JJJJ emission factors may not be utilized in lieu of catalyst manufacture specifications when a catalyst is

installed, and the catalysts manufacturer achieves higher control efficiency.

Flare Manufacturer specifications

Oil/Liquid Analysis: This data is required to match the inputs in all applicable emission calculations. For facilities

that have not been constructed and a representative analysis is used it cannot be older than 1 year. For existing

facilities, the gas analyses required by Condition A201.A (must be 1 year old or less).

Gas Analysis (must be 1 year old or less) This data is required to match the inputs in all applicable emission

calculations.

Extended Gas Analysis (must be 1 year old or less) This data is required to match the inputs in all applicable emission

calculations.

If requesting to use a representative gas sample, include a discussion of why the sample is representative for this

facility and an explanation of how it is representative (e.g., same reservoir, same similar API gravity, similar

composition).

If test data are used, to support emissions calculations or to establish allowable emission limits, include a copy of the complete test report. If the test data are for an emissions unit other than the one being permitted, the emission units

must be identical. Test data may not be used if any difference in operating conditions of the unit being permitted and

the unit represented in the test report significantly effect emission rates.

Fuel specifications sheet. If computer models are used to estimate emissions, include an input summary and a detailed report, and a disk containing the input file used to run the model.

For tank-flashing emissions, include a discussion of the method used to estimate tank-flashing emissions, accuracy of

the model, the input and output summary from simu

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