HomeMy WebLinkAbout20170208.tiffCOLORADO
Department of Public
Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
January 10, 2017
Dear Sir or Madam:
RECEIVED
JAN 1 3 2017
WELD COUNTY
COMMISSIONERS
On January 12, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
Verdad Oil and Gas Corporation - Highland 29-1N. A copy of this public notice and the public
comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Regards,
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor
?obi 1R .v i cc -0
at/93i( 1
Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
cc PLC Min/ 7-P) HLC P )
P(&) CZRCCH / TrY)/ CI(*)
O I / i (o / ( -7
2017-0208
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Verdad Oil and Gas Corporation - Highland 29-1N - Weld County
Notice Period Begins: January 12, 2017
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Verdad Oil and Gas Corporation
Facility: Highland 29-1N
Oil and Gas Exploration and Production Facility
SWNE Sec 29 T1 N R65W
Weld County
The proposed project or activity is as follows: The applicant proposes to operate a new exploration and
production facility, consisting of Compression engine, condensate tanks, separator venting, produced water
tanks, and condensate loadout.
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.C due to the following reason(s):
• permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section
III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area)
• the source is requesting a federally enforceable limit on the potential to emit in order to avoid other
requirements
The Division has made a preliminary determination of approval of the application.
A copy of the application, the Division's analysis, and a draft of Construction Permit 16WE0767 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Any such comment must be submitted in writing to the following addressee:
David Thompson
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
COLORADO
1 IAy
Division Information
Engineer:
David Thompson
Control Engineer:
Steph Spector
Review Date:
09/20/2016
Application Date:
06/23/2016
Facility Identifiers
Permit No.
16WE0767
AIRS
County #
123 'Weld
Facility #
9E95
Facility Type:
exploration and production facility
O Located in the 8 -hour non -attainment area?
Administrative Information
Potentially Located within EAC - determine attain
0 True Minor
O Synthetic Minor for:
i— voc
Company Name:
Verdad Oil and Gas Corporation
Source Name:
Highland 29-1N
Source Location:
SIC:
SWNE Sec 29, t1 N, R65W
1311
Mailing
Address
Address 1:
Address 2:
ty, State Zip:
Verdad Oil and Gas Corporation
5950 Cedar Springs Road, Suite 200
Dallas, TX 75235
Person To
Contact
Name:
Phone:
Fax:
Email:
Arthur Beecherl
214-728-1840
000-000-0000
abeecherl@verdadoil.com
Requested Action
Self Certification Required?
Issuance Number:
Yes
1
NOx rco
Source Description:
Oil and gas exploration and production facility known as the Highland 29-1 N, located in the SWNE Sec 29, t1 N,
R65W, Weld County, Colorado.
Point
Name
Type
Control
Action
001
Compressor
Engine
Catalytic
Oxidizer
Newly
reported
source
002
Fugitives
Fugitives
None
Cancelled
003
Condensate
Storage
Tanks
Condensate
Tanks
Flare
Newly
reported
source
004
Condensate
Loading
Loadout
None
newly
reported
source
005
Separators
Separator Venting
Flare
Newly
reported
source
006
Produced
Water
Water Tanks
Flare
Newly
reported
source
Division Information
Engineer:
David Thompson
Control Engineer:
Steph Spector
Review Date:
09/22/2016
Application Date:
05/26/2016
Facility Identifiers
Permit No.
16WE0767
AIRs
County #
123 Weld
Facility #
9E95
Point #
001
Facility Equipment ID
Compressor
Section 01: Administrative Information
Attainment Status
PM10
Attainment
PM2.5
Attainment
SOx
Attainment
NOx
Nonattainment
VOC
Nonattainment
CO
Attainment
Potentially Located within EAC - determine attainr
Company Name:
Verdad Oil and Gas Company
Source Name:
Highland 29-1N
Source Location:
SNE Sec 29 Ti N R65W
W
SIC:
1311
Elevation (feet)
0
Mailing
Address
Address 1:
Address 2:
City, State Zip:
Verdad Oil and Gas Company
5950 Cedar Springs Road, Suite 200
Dallas TX, 75235
Contact
Name:
Arthur Beecherl
Section 02: Requested Action
Iv New permit/newly reported emission
✓ Request MOD - Change fuel/equipment
r Request MOD - Change permit limit
✓ Request MOD - Change company name
✓ Request MOD - Transfer of ownership
✓ Request MOD - Other
Issuance Number: 1
r Request portable source permit
If this is an exemption, enter XA or XP here
Add'I Info and
notes:
Section 03: General Facility Information
General description of equipment
purpose:
This emission unit is used for natural gas compression.
Date the engine was ordered:
10/7/2015
Date engine construction commenced:
12/11/2015
Date engine relocated into Colorado:
10/1/2015
Date of any reconstruction/modification:
1/1/1900
Will this equipment be operated in any nonattainment area?
Yes
Section 04: Engine Information
Engine Info
Engine date of mfg
2/1/20151
Engine Displacement
5.7 Ucyl
Manufacturer:
General Motors
Model Number:
FX 10Q
Serial Number:
10CHMM502250021
Engine Function
Compression
berating
Mfg's Max. Rated Horsepower @ sea level: 192
C Derate Based on Altitude:
C Derate by a factor ofi
C Use Site -Specific Rating:
a No Deration
3 % for every
500 feet over
3000 feet of altitude
0.5
1000
hp
Horsepower used for calcuations:
92
BSCF @ 100% Load (btu/hp-hr):
8500
Site - Rated BSCF @ 100% load (btu/hp-hr):
8500
BSCF: Site -Rated value will be used when available
Other
Parameters
Engine Type
4SRB
Aspiration
naturally aspirated
Electrical Generator Max Site Rating (kw)
0
Annual hours for PTE
8760
Annual hours for permit
8760
<-Optional: Use generator rating to estimate horsepower
instead of derating and mfg value above
Assumed efficiency: 75.0%
Section 06: Fuel Consumption Information
Fuel Use Rate @ 100% Load
823 scf/hr
ACTUAL Annual Fuel
Consumption
7.21 MMscf/yr
MAX POTENTIAL Annual Fuel
Consumption
7.210 MMscf/yr
REQUESTED Annual Fuel
Consumption
7.210 MMscf/yr
Fuel Heating Value
950.25 btu/scf
<-Optional: Use default fuel heating values
<-Optional: Use BSCF & FHV to estimate Max potential
Annual Fuel Consumption
Section 07: Emission Control Information
Primary Control Device Description
CHOOSE ONE and delete the
non -selective catalytic reduction (NSCR) system and air -fuel ratio control
Uncontrolled Emission Factors - Criteria & HCHO
Pollutant
Value - lb/MMBtu
Value - g/bhp-hr
Source/Comments
NOx
3.631
14.000
CO
2.853
11.000
VOC
0.182
0.700
Formaldehyde
0.021
0.079
Use ? Button to find a default set of values.
Use ! Button to enter value in one set of units and have the program find the other one
NOTE: the program needs to have values in both unit sets entered, please
Control Efficiency/Controlled Emission Factors - Criteria & HCHO
Pollutant
Value - lb/MMBtu
Value - g/bhp-hr
Control (%)
Source/Comments
NOx
0.254
0.980
93.0%
CO
0.514
1.980
82.0%
VOC
0.182
0.700
0.0%
Formaldehyde
0.021
0.079
0.0%
For each controlled pollutant, enter one of the following: b/mmbtu, g/bhp-hr or %.
Then press button to calculate the rest.
NOTE: the program needs to have all values entered, please
Other Pollutants - Emission Factors and Controls
Step 1 Choose a set of uncontrolled emission factors for SO2, PM, PM10, PM2.5 and
Option A: Choose one set for everything (i.e. AP -42)
Option B: Choose the highest value for each pollutant (i.e., some will be AP -42, some will
Option C: Write in a value for each pollutant yourself
Option D: Run option A or B for all pollutants, and then Run Option C to overwrite a few vs
Step 2 Enter a control efficiencies (if applicable) for SO2, PM, PM10, PM2.5 and NCRP
Ignore step 2 if the engine is uncontrolled.
MACT ZZZZ
Facility HAP Status Area Source
Is the engine an emergency RICE under 7777 definitions? No
Is the engine a limited use RICE under 7777 definitions? No
Is the engine a landfill/digester gas RICE under 7777 definitions? No
MACT 7777 Category: New/Recon 4SRB
less than or equal to 500 HP
The permit document will include guidance about what MACT 7777 conditions to include based on the MACT ;
NSPS JJJJ
Currently this rule is not adopted into Reg No. 6, the permit only addresses NSPS JJJJ in the notes to permit he
Regulation No. 7 - Section XVII.E (Statewide Standards)
Based on the dates and horsepowers listed above, the following standards apply:
HP
Con/Relocate Date
NOx
CO
VOC
NA
January 1, 2011
NA
NA
NA
Engine meets stds preconrol?
NA
NA
NA
Engine meets stds postcontrol?
NA
NA
NA
Final Calculations
Click this button AFTER all entries on this page are complete to finalize calculations on the
"Emission Calculations" Tab.
Summary of Preliminary Analysis - NG RICE
Company Name Verdad Oil and Gas Company
Facility Name Highland 29-1N
Facility Location SWNE Sec 29 Ti N R65W
Facility Equipment ID Compressor
Permit No.
AIRS
Review Date
Permit Engineer
16WE0767
123/9E95/001
09/22/2016
David Thompson
Requested Action New permit/newly reported emission
Issuance No. 1
Emission Point Description
One (1) General Motors, Model FX 10Q, Serial Number 10CHMM502250021, natural gas -fired, naturally aspirated, 4SRB
reciprocating internal combustion engine, site rated at 92 horsepower. non -selective catalytic reduction (NSCR) system and
air -fuel ratio control This emission unit is used for natural gas compression.
Natural Gas Consumption
Requested (mmscf/yr)
7.21
Requested (mmscf/m)
0.61
Fuel Heat Value (btu/scf)
950.25
BSCF (Btu/hp-hr)
8500
Emission Factor Sources
Hours of Operation
PTE Calculated at (hpy)
Permit limits calculated at (hpy)
8760
8760
Uncontrolled
Controlled
NOx
o
0
VOC
0
0
CO
o
0
Formaldehyde
o.00
0
SOx
AP -42; Table 3.2-3 (7/2000); Natural Gas
No Control
TSP
AP -42; Table 3.2-3 (7/2000); Natural Gas
No Control
PM10
AP -42; Table 3.2-3 (7/2000); Natural Gas
No Control
PM2.5
AP -42; Table 3.2-3 (7/2000); Natural Gas
No Control
Other Pollutants
Describe EF sources - HAPs etc.
Describe EF sources - HAPs, etc.
Point Summary of Criteria Emissions (t
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
NOx
12.4
0.9
12.4
93.0%
VOC
0.6
0.6
0.6
0.0%
CO
9.8
1.8
9.8
82.0%
SOx
0.0
0.0
0.0
0.0%
TSP
0.1
0.1
0.1
0.0%
PM10
0.1
0.1
0.1
0.0%
PM2.5
0.1
0.1
0.1
0.0%
Total HAPs*
0.0
0.0
0.1
0.0%
*Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de
minimus thresholds. PTE includes all HAPs calculated, even those below de minimus.
Point Summary of Hazardous Air Pollutants (lb/yr
HAP Name
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
Formaldehyde
*
*
140
0.0%
Methanol
*
*
21
0.0%
Acetaldehyde
*
*
19
0.0%
Acrolein
*
*
18
0.0%
Benzene
*
*
11
0.0%
1,3 -Butadiene
*
*
5
0.0%
Toluene
*
*
4
0.0%
*Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED
UNCONTROLLED is greater than de minimus
Permitting Requirements
Ambient Air Impacts
Source is not required to model based on Division Guidelines
Public Comment
Public Comment Required
MACT 777Z
New/Recon 4SRB less than or equal to 500 HP located at a(n) Area Source
Reg 7 XVII.E
Standards (g/hp-hr)
NOx: NA CO: NA VOC: NA
Reg 7 XVI.B (Ozone NAA
requirements) applies?
No
MACT ZZZZ (area source)
Is this engine subject to MACT 7777 area
Yes
source requirements?
NSPS JJJJ
Is this engine subject to NSPS JJJJ?
Yes
Note: JJJJ requriements are not currently included as permit conditions because the reg has not
been adopted into Reg 6.
Comments/Notes
0
Preliminary Analysis: RICE
Emission Calculations - NG RICE
Company Name Verdad Oil and Gas Company
Permit No. 16WE0767
AIRS 123/9E95/001
Engine Type 4SRB
Throughputs
Requested Fuel Consumption (MMBtu/yr)
Max Potential Fuel Consumption (MMBtu/yr)
Actual Fuel Consumption (MMBtu/yr)
MMBtu/yr
MMscf/yr
6851.303
6851.303
6851.303
7.21
7.21
7.21
Emissions (tpy) - Criteria
PM10
PM2.5
TSP
5O2
NOx
VOC
CO
Uncontrolled Requested Emissions
0.1
0.1
0.1
0.0
12.4
0.6
9.8
Controlled Requested Emissions
0.1
0.1
0.1
0.0
0.9
0.6
1.8
PTE
0.1
0.1
0.1
0.0
12.4
0.6
9.8
Uncontrolled Actual Emissions
0.066492
0.002014
12.439013
0.62195064
9.77351
Controlled Actual Emissions
0.066492
0.002014
0.8707309
0.62195064
1.759232
Emission Factors - Criteria
PM10
PM2.5
TSP
SO2
NOx
VOC
CO
lb/MMBtu - Uncontrolled
0.019
0.019
0.019
0.001
3.631
0.182
2.853
Ib/MMBtu - Controlled
0.019
0.019
0.019
0.001
0.254
0.182
0.514
% Control
0.0
0.0
0.0
0.0
93.0%
0.0%
82.0%
Emission Factor Sources/Notes:
Controlled
Uncontrolled
PM10
No Control
AP -42; Table 3.2-3 (7/2000); Natur
SO2
No Control
AP -42; Table 3.2-3 (7/2000); Natur
NOx
0
0
VOC
0
0
CO
0
0
PM2.5
No Control
AP -42; Table 3.2-3 (7/2000); Natur
TSP
No Control
AP -42; Table 3.2-3 (7/2000); Natur
Printed 1/6/2017
Colorado Department of Public Health Envrionment
Air Pollution Control Division
Page 9 of 31
Preliminary Analysis: RICE
Emission Calculations
Company Name Verdad Oil and Gas Company
Permit No. 16WE0767
AIRS 123/9E95/001
Emissions - NCRPs
Colorado Department of Public Health Envrionment
Air Pollution Control Division
Pollutant
Formaldehyde
Methanol
Acetaldehyde
Acrolein
Benzene
1,3 -Butadiene
Toluene
CAS
BIN
50000 A
Requested
Controlled
lb/yr
Uncontrolled
lb/yr
PTE
lb/yr
Actual
Controlled I Uncontrolled
lb/yr Ib/yr
Cont. Req.
actual>Rep
lb/yr
140.5 140.5 140.5 140.5 140.5 0.0
67561 C 21.0 21.0 21.0 21.0 21.0 0.0
75070 A 19.1 19.1 19.1 19.1 19.1 0.0
107028 A 18.0 18.0 18.0 18.0 18.0 0.0
71432 A 10.8 10.8 10.8 10.8 10.8 0.0
106990 A 4.5 4.5 4.5 4.5 4.5 0.0
108883 C 3.8 3.8 3.8 3.8 3.8 0.0
Xylene 1330207 C 1.3 1.3 1.3 1.3 1.3 0.0
0 0 1.0 1.0 1.0 1.0 1.0 0.0
Naphthalene 91203 B 0.7 0.7 0.7 0.7 0.7 0.0
Methylene Chloride 75092 A 0.3 0.3 0.3 0.3 0.3 0.0
1,1,2,2-Tetrachloroethane 79345 A 0.2 0.2 0.2 0.2 0.2 0.0
Ethylbenzene 100414 C 0.2 0.2 0.2 0.2 0.2 0.0
Ethylene Dibromide 106934 A 0.1 0.1 0.1 0.1 0.1 0.0
Carbon Tetrachloride 56235 A 0.1 0.1 0.1 0.1 0.1 0.0
1,1,2-Trichloroethane 79005 A 0.1 0.1 0.1 0.1 0.1 0.0
Chloroform 67663 A 0.1 0.1 0.1 0.1 0.1 0.0
Chlorobenzene 108907 A 0.1 0.1 0.1 0.1 0.1 0.0
1,3-Dichloropropene 542756 A 0.1 0.1 0.1 0.1 0.1 0.0
Styrene 100425 C 0.1 0.1 0.1 0.1 0.1 0.0
1,1-Dichloroethane 75343 B 0.1 0.1 0.1 0.1 0.1 0.0
Vinyl Chloride 75014 A 0.0 0.0 0.0 0.0 0.0 0.0
2-Methylnaphthalene 91576 0 0.0 0.0 0.0 0.0 0.0 0.0
2,2,4-Trimethylpentane 540841 C 0.0 0.0 0.0 0.0 0.0 0.0
Acenaphthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Acenaphthylene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Anthracene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benz(a)anthracene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benzo(a)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benzo(b)fluoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benzo(e)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benzo(g,h,i)perylene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Benzo(k)fluoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Biphenyl 92524 C 0.0 0.0 0.0 0.0 0.0 0.0
Chrysene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Fluoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
Fluorene 7782414 C 0.0 0.0 0.0 0.0 0.0 0.0
Indeno(1,2,3-c,d)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0
n -Hexane 110543 C 0.0 0.0 0.0 0.0 0.0 0.0
PAH
Printed 1/6/2017
PTE
>Reportable
lb/yr
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Unc. Requested
actual>Rep
lb/yr
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Page 10 of 31
Preliminary Analysis: RICE
Emission Calculations
Company Name Verdad Oil and Gas Company
Permit No. 16WE0767
AIRS 123/9E95/001
Emission Factors - NCRPs
Colorado Department of Public Health Envrionment
Air Pollution Control Division
Pollutant
Formaldehyde
Methanol
Acetaldehyde
Acrolein
Benzene
1,3 -Butadiene
Toluene
Xylene
PAH
Naphthalene
Methylene Chloride
1,1,2,2-Tetrachloroethane
Ethylbenzene
Ethylene Dibromide
Carbon Tetrachloride
1,1,2-Trichloroethane
Chloroform
Chlorobenzene
1,3-Dichloropropene
Styrene
1,1-Dichloroethane
Vinyl Chloride
2-Methylnaphthalene
2,2,4-Trimethylpentane
Acenaphthene
Acenaphthylene
Anthracene
Benz(a)anthracene
Benzo(a)pyrene
Benzo(b)fluoranthene
Benzo(e)pyrene
Benzo(g,h,i)perylene
Benzo(k)fluoranthene
Biphenyl
Chrysene
Fluoranthene
Fluorene
Indeno(1,2,3-c,d)pyrene
n -Hexane
CAS
Controlled
Uncontrolled
Emission Factor
lb/MMBtu % Control Notes
50000 0.0205 0.07903858 0.0%
Emission Factor
IbIMMBtu I glbhp-hr Notes
0 0.02 0.07904 0.00
0 0.00306 0.011797954 0.0% No Control
0 0.00279 0.010756958 0.0% No Control
0 0.00263 0.010140072 0.0% No Control
O 0.00158 0.006091754 0.0% No Control
O 0.000663 0.002556223 0.0% No Control
O 0.000558 0.002151392 0.0% No Control
O 0.000195 0.00075183 0.0% No Control
O 0.000141 0.000543631 0.0% No Control
O 0.0000971 0.000374373 0.0% No Control
0 0.0000412 0.000158848 0.0% No Control
O 0.0000253 9.75452E-05 0.0% No Control
O 0.0000248 9.56174E-05 0.0% No Control
0 0.0000213 8.2123E-05 0.0% No Control
0 0.0000177 6.82431E-05 0.0% No Control
O 0.0000153 5.89898E-05 0.0% No Control
O 0.0000137 5.28209E-05 0.0% No Control
O 0.0000129 4.97365E-05 0.0% No Control
O 0.0000127 4.89654E-05 0.0% No Control
O 0.0000119 4.58809E-05 0.0% No Control
0 0.0000113 4.35676E-05 0.0% No Control
O 0.00000718 2.76828E-05 0.0% No Control
0 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
O 0 0 #DIV/o! No Control
O 0 0 #DIV/0! No Control
0 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
O 0 0 #DIV/0! No Control
0.00306 0.0118 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.00279 0.01076 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.00263 0.01014 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.00158 0.00609 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.000663 0.00256 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.000558 0.00215 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.000195 0.00075 AP -42; Table 3.2-3 (7/2000); Natural Gas
0.000141 0.00054 AP -42; Table 3.2-3 (7/2000); Natural Gas
9.71 E-05 0.00037 AP -42; Table 3.2-3 (7/2000); Natural Gas
4.12E-05 0.00016 AP -42; Table 3.2-3 (7/2000); Natural Gas
2.53E-05 9.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
2.48E-05 9.6E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
2.13E-05 8.2E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.77E-05 6.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.53E-05 5.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.37E-05 5.3E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.29E-05 5E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.27E-05 4.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.19E-05 4.6E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
1.13E-05 4.4E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
7.18E-06 2.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
O 0 AP -42; Table 3.2-3 (7/2000); Natural Gas
Printed 1/6/2017
Page 11 of 31
Natural Gas -Fired Reciprocating Internal Combustion Engines
Emission Factors - 4SRB
1
Uncontrolled
Uncontrolled
Controlled
Controlled
AP -42
Value Used
Value Used - comments
Value Used
Value used - comments
Table 3.2-3 (7/2000)
(Ib/MMBtu)
(lb/MMBtu)
Natural Gas
Pollutant
CAS
BIN
lb/MMBtu
NOx
3.63
0
0.254179667
0
2.21
CO
2.85
0
0.513546674
0
3.72
VOC
0.18
0
0.181556905
0
2.96E-02
Formaldehyde
50000
A
0.02
0
0.0205
0
2.05E-02
SO2
0.000588
AP -42; Table 3.2-3 (7/2000);
0.000588
No Control
5.88E-04
PM10
0.01941
AP -42; Table 3.2-3 (7/2000);
0.01941
No Control
0.01941
PM2.5
0.01941
AP -42; Table 3.2-3 (7/2000);
0.01941
No Control
0.01941
TSP
0.01941
AP -42; Table 3.2-3 (7/2000);
0.01941
No Control
0.01941
1,1,2,2-Tetrachloroethane
79345]A
0.0000253
AP -42; Table 3.2-3 (7/2000);
0.0000253
No Control
2.53E-05
1,1,2-Trichooroethane
79005
A
0.0000153
AP -42; Table 3.2-3 (7/2000);
0.0000153
No Control
1.53E-05
1,1-Dichloroethane
75343
B
0.0000113
AP -42; Table 3.2-3 (7/2000);
0.0000113
No Control
1.13E-05
1,3 -Butadiene
106990
A
0.000663
AP -42; Table 3.2-3 (7/2000);
0.000663
No Control
6.63E-04
1,3-Dichloropropene
542756
A
0.0000127
AP -42; Table 3.2-3 (7/2000);
0.0000127
No Control
1.27E-05
2-Methylnaphthalene
91576
AP -42; Table 3.2-3 (7/2000);
0
No Control
2,2,4-Trimethylpentane
540841
C
AP -42; Table 3.2-3 (7/2000);
0
No Control
Acenaphthene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Acenaphthylene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Acetaldehyde
75070
A
2.79E-03
AP -42; Table 3.2-3 (7/2000);
0.00279
No Control
2.79E-03
Acrolein
107028
A
0.00263
AP -42; Table 3.2-3 (7/2000);
0.00263
No Control
2.63E-03
Anthracene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benz(a)anthracene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benzene
71432
A
1.58E-03
AP -42; Table 3.2-3 (7/2000);
0.00158
No Control
1.58E-03
Benzo(a)pyrene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benzo(b)fluoranthene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benzo(e)pyrene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benzo(g,h,i)perylene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Benzo(k)fluoranthene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Biphenyl
92524
C
AP -42; Table 3.2-3 (7/2000);
0
No Control
Carbon Tetrachloride
56235
A
0.0000177
AP -42; Table 3.2-3 (7/2000);
0.0000177
No Control
1.77E-05
Chlorobenzene
108907
A
0.0000129
AP -42; Table 3.2-3 (7/2000);
0.0000129
No Control
1.29E-05
Chloroform
67663
A
0.0000137
AP -42; Table 3.2-3 (7/2000);
0.0000137
No Control
1.37E-05
Chrysene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Ethylbenzene
100414
C
0.0000248
AP -42; Table 3.2-3 (7/2000);
0.0000248
No Control
2.48E-05
Ethylene Dibromide
106934,A
0.0000213
AP -42; Table 3.2-3 (7/2000);
0.0000213
No Control
2.13E-05
Fluoranthene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Page 12 of 31
Printed 1/6/2017
Natural Gas -Fired Reciprocating Internal Combustion Engines
Emission Factors - 4SRB
1
Uncontrolled
Uncontrolled
Controlled
Controlled
AP -42
Value Used
Value Used - comments
Value Used
Value used - comments
Table 3.23 (7/2000)
(lb/MMBtu)
(lb/MMBtu)
Natural Gas
Pollutant
CAS
BIN
lb/MMBtu
Fluorene
7782414
C
AP -42; Table 3.2-3 (7/2000);
0
No Control
Indeno(1,2,3-c,d)pyrene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Methanol
67561 C
0.00306
AP -42; Table 3.2-3 (7/2000);
0.00306
No Control
3.06E-03
Methylene Chloride
75092 A
0.0000412
AP -42; Table 3.2-3 (7/2000);
0.0000412
No Control
4.12E-05
n -Hexane
110543 C
AP -42; Table 3.2-3 (7/2000);
0
No Control
Naphthalene
91203 B
0.0000971
AP -42; Table 3.2-3 (7/2000);
0.0000971
No Control
9.71 E-05
PAH
0.000141
AP -42; Table 3.2-3 (7/2000);
0.000141
No Control
1.41 E-04
Phenanthrene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Phenol
1089521 C
AP -42; Table 3.2-3 (7/2000);
0
No Control
Pyrene
AP -42; Table 3.2-3 (7/2000);
0
No Control
Styrene
100425 C
0.0000119
AP -42; Table 3.2-3 (7/2000);
0.0000119
No Control
1.19E-05
Tetrachloroethane
79345
A
AP -42; Table 3.2-3 (7/2000);
0
No Control
Toluene
108883
C
0.000558
AP -42; Table 3.2-3 (7/2000);
0.000558
No Control
5.58E-04
Vinyl Chloride
75014
A
0.00000718
AP -42; Table 3.2-3 (7/2000);
0.00000718
No Control
7.18E-06
Xylene
1330207
C
0.000195
AP -42; Table 3.2-3 (7/2000);
0.000195
No Control
1.95E-04
Page 13 of 31
Printed 1/6/2017
Natural Gas -Fired Reciprocating Internal Combustion Engines
Emission Factors - 4SRB
2
3
4
5
GRI HAPCaIc 3.0
GRI HAPCaIc 3.0
GRI HAPCaIc 3.0
GRI HAPCaIc 3.0
Literature
Literature
Test Data
Test Data
Natural Gas
Field Gas
Natural Gas
Field Gas
Pollutant
CAS
BIN
g/bhp-hr
g/bhp-hr
g/bhp-hr
g/bhp-hr
NOx
18.3
7.53
CO
14.5
9.08
VOC
0.264
Formaldehyde
50000
A
0.0623
0.0381
0.0994
0.0418
SO2
PM10
PM2.5
TSP
1,1,2,2-Tetrachloroethane
79345
A
1,1,2-Trichloroethane
79005
A
1,1-Dichloroethane
75343
B
1,3 -Butadiene
106990
A
1,3-Dichloropropene
542756
A
2-Methylnaphthalene
91576
5.05E-05
2,2,4-Trimethylpentane
540841
C
Acenaphthene
1.09E-05
Acenaphthylene
1.89E-05
Acetaldehyde
75070
A
0.0039
Acrolein
107028
A
0.0034
Anthracene
4.00E-06
Benz(a)anthracene
1.80E-06
Benzene
71432
A
0.0046
0.0221
0.0221
Benzo(a)pyrene
4.00E-07
Benzo(b)fluoranthene
2.20E-06
Benzo(e)pyrene
Benzo(g,h,i)perylene
7.00E-07
Benzo(k)fluoranthene
2.20E-06
Biphenyl
92524
C
Carbon Tetrachloride
56235
A
Chlorobenzene
108907
A
Chloroform
67663
A
Chrysene
2.20E-06
Ethylbenzene
100414
C
Ethylene Dibromide
106934A
Fluoranthene
1.26E-05
Page 14 of 31 Printed 1/6/2017
Natural Gas -Fired Reciprocating Internal Combustion Engines
Emission Factors - 4SRB
2
3
4
5
GRI HAPCalc 3.0
GRI HAPCalc 3.0
GRI HAPCalc 3.0
GRI HAPCalc 3.0
Literature
Literature
Test Data
Test Data
Natural Gas
Field Gas
Natural Gas
Field Gas
Pollutant
CAS BIN
g/bhp-hr
g/bhp-hr
g/bhp-hr
g/bhp-hr
Fluorene
7782414
C
1.72E-05
Indeno(1,2,3-c,d)pyrene
5.00E-07
Methanol
67561
C
0.02
0.00667
Methylene Chloride
75092
A
n -Hexane
110543
C
Naphthalene
91203
B
2.75E-04
PAH
Phenanthrene
3.21 E-05
Phenol
108952
C
Pyrene
8.60E-06
Styrene
100425
C
Tetrachloroethane
79345
A
Toluene
108883
C
0.002
0.007
7.10E-03
Vinyl Chloride
75014
A
Xylene
1330207 C
0.0014
0.0017
1.70E-03
Page 15 of 31 Printed 1/6/2017
COLORADO DEPARTMENT OF PUBLIC HEALTH ENVIRONMENT
AIR POLUTION CONTROL DIVISION
INVENTORY
AIRS (County/Plant) 123/9E95/001
Permit No. 16WE0767
Date 9/22/2016
Engine Type 4SRB
Point #
Seg *
SCC
Pollutant or CAS
Fug
Dust
Uncontrolled
Emission Factor
Emisison Factor Source
Controlled
Actual
Emissions
(tpy)'
Controlled
Requested
Emissions
(tpy)*
PTE (tpy)*
Ctrl.
Eff%
NCRP =
reportable
?
001
2-02-002-53
NOx
n
3450.49 lb/MMscf
0
0.9
0.9
12.4
93%
CO
n
2711.1 Ib/MMscf
0
1.8
1.8
9.8
82%
VOC
n
172.524 lb/MMscf
0
0.6
0.6
0.6
0%
50000
Formaldehyde
n
19.4801 lb/MMscf
0
140
140
140
0%
No
67561
Methanol
n
2.90777 lb/MMscf
AP -42; Table 3.2-3 (72000); Natural Gas
21
21
21
0%
No
75070
Acetaldehyde
n
2.6512 lb/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
19
19
19
0%
No
107028
Acrolein
n
2.49916 lb/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
18
18
18
0%
No
71432
Benzene
n
1.5014 lb/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
11
11
11
0%
No
106990
1,3 -Butadiene
n
0.63002 lb/MMscf
AP -42; Table 3.2-3 (72000); Natural Gas
5
5
5
0%
No
108883
Toluene
n
0.53024 lb/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
4
4
4
0%
No
1330207
Xylene
n
0.1853 lb/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
1
1
1
0%
No
0
PAH
n
0.13399 Ib/MMscf
AP -42; Table 3.2-3 (7/2000); Natural Gas
1
1
1
0%
No
91203
Naphthalene
n
0.09227 Ib/MMscf
AP -42; Table 3.2-3 (72000); Natural Gas
1
1
1
0%
No
NOTES
*Emissions of criteria are reported in tons/yr; emissions of NCRPs are in lb/yr.
Engine BSCF: 8500 Btu/hp-hr
Engine HP: 92
Fuel Heat Value: 950.25 btu/scf
Controlled emissions shown above are calculated using the control efficiencies/factors specified, at the permitted fuel use rate (calculated at 8760 hpy)
PTE shown above is calculated based on the uncontrolled emission factors and the maximum potential fuel use rate (calculated at 8760 hpy)
You can copy each row into the permit history file for a facility -wide summary.
The first row can be copied into the Criteria tab.
The second and third rows can be copied into the HAPs tab.
Be sure to do Edit, Paste Special, Values to avoid creating links back to this PA in the history file.
Contr
POINT
PERMIT
Description
NOx
VOC
Fug VOC
CO
001
16WE0767
General Motors FX 10Q 92HP
0.9
0.6
1.8
Controlled Emissions
POINT
PERMIT
Description
General Motors FX 10Q 92HP
Formaldehyde
Acetaldehyde
Benzene
Acrolein
001 16WE0767
140
19
Uncontrolled
11
18
POINT
PERMIT
Description
General Motors FX 10Q 92HP
Formaldehyde
Acetaldehyde
Benzene
Acrolein
001 16WE0767
140
19
11
18
Notes:
Controlled emissions shown above are calculated using the control efficiencies/factors specified on the d
Uncontrolled emissions shown above are calculated based on uncontrolled EFs specified on the data en
Uncontrolled Emissions
Reportable
HAPs
Total
HAPs
NOx
VOC
Fug VOC
CO
Reportabl
e HAPs
Total
HAPs
12.4
0.6
9.8
Toluene
Ethylbenzene
Xylene
n -Hexane
2,2,4 -Trim
Methanol
1,3 -Butadiene
4
0
1
0
0
21
5
Toluene
Ethylbenzene
Xylene
n -Hexane
2,2,4 -Trim
Methanol
1,3 -Butadiene
4
0
1
0
0 21 5
lata entry sheet, at the permitted fuel use rate (calculated at 8760 hpy)
try sheet, at the maximum potential fuel use rate (calculated at 8760 hpy)
Preliminary Analysis - NG RICE
Modeling
Model Inauts (Facili.
Permit:
16WE0767
Source Type
Point
Emission Rate - NOx
2.5E-02 g/sec Source: NOx annual rate calculated in
Preliminary Analysis
Emission Rate - NO2
1.9E-02 g/sec (NO2 = NOx rate * 0.75)
Release Height
10 meters
Receptor Height
0 meters
Stack Height
0 ft
Exit Temperature
0 °F
Inside Diameter
0 ft
Exit Velocity
0 fUsec
Urban/Rural
Rural
Model Results (Facili.
Maximum Impact from model (1 -hr concentration):
0 µg/m3 NO2
Max Impact occurs at (distance):
0 meters
Convert 1 -hr concentration to Annual Concentration
0.00 µg/m3 (annual conc. = 1 -hr conc. x 0.08)
Background Concentration
Annual Concentration: I 0µg/m'
Source: Ambient Background Concentration Database (October, 2005)
Region: #
Subregion: X - XXX
Total Impacts (Facility + Background.
Total Impacts
(µg/m3)
Ambient
Standard
(µg/m3)
Complies with
Ambient
Standard?
Annual Concentration:
0.0
100
Yes
1/6/2017
003 Three (3) above ground 300 bbl atmospheric condensate storage tank
Requsted Throughput
91250
bbl
Control
Flare
Efficiency
95.00%I
Emissions Summary Table
Pollutant
Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
V0C
8.40676
lb/bbl
383.6 tpy
19.2 tpy
E&P TANK
Benzene
0.023312
lb/bbl
2127.22 lb/yr
106.361 lb/yr
E&P TANK
n -Hexane
0.1221
lb/bbl
11141.625 lb/yr
557.0813 lb/yr
E&P TANK
Regulatory Review
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall
allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This
standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The
approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60,
Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation.
Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a
smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the
atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more
than six minutes in any sixty consecutive minutes.
Regulation 2'— Odor
Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants
from any single source such as to result in detectable odors which are measured in excess of the following
limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are
detected after the odorous air has been diluted with seven (7) or more volumes of odor free air.
Regulation 6 - New Source Performance Standards
NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84.
This source is not subject because each tank is less than 19,800 gallons (471 bbl)
NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing
segments.
This source is not subject because each tank emits less than 6 tpy VOC.
Regulation 7 —Volatile Organic Compounds
XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS
(Applicant is not subject to the emission control requirements for condensate tanks since it is
located in an attainment area.)
XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS...
(Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of
VOC.)
004 Hydrocarbon Loadout to Tanker Trucks
Calculations
L = 12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1)
L = loading losses in lb per 1000 gallons loaded
The table of inputs below enables you to
calculate the loading loss emissions factor
"L". If you choose to use a state default
emissions factor, you may enter is directly
into cell B14 in units lb/1,000 gallons which
Factor
Meaning
Value
Units
Source
S
Saturation Factor
0.6
AP -42
P
True Vapor Pressure
5.8692
psia
Sales Oil A
M
Molecular Weight of Val
41.07
lb/lb-mole
AP -42
T
Liquid Temperature
520
deg. R
Field Data
L
3.47 lb/10^3 gal
1.46E-01 lb/bbl
Annual requested Throughput
Annual requested VOC emissions
Control: None
Efficiency: 0.00%
NCRPs
Component
Mass Fraction
Benzene
0.0035
n -hexane
0.0187
Toluene
Xylenes
Source:
109500 BBL/yr
4599000 gal/yr
15938 lb/yr
7.97 tpy
nalysis
If the operator provides HAP speciation from a stable "sales
oil" analysis, enter the mass fraction from this data.
Alternatively, if the operator modeled a pressurized oil to
develop a site specific emissions factor, enter the modeled
Pressurized oil or Stable Sales Oil Analysis
Emissions Summary Table
Pollutant
Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
0.1456
lb/bbl
8.0 tpy
8.0 tpy
AP -42
Benzene
0.0005
lb/bbl
55.0 lb/yr
55.0 lb/yr
AP -42
n -Hexane
0.0027
lb/bbl
299 lb/yr
299 lb/yr
AP -42
Toluene
0.0000
lb/bbl
0 lb/yr
0 lb/yr
AP -42
Xylenes
0.0000
lb/bbl
0 lb/yr
0 lb/yr
AP -42
Regulatory Review
Regulation 3 - APEN and Permitting Requirements
Is this site considered an exploration and production location (e.g. well pad)?
If yes, review the following two exemptions for applicability:
Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1
Does this operator unload less than 6,750 bbls per year of condensate via splash fill or
16,308 bbls per year of condensate via submerged fill procedure? No
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1
Yes
No
Produced Natural Gas Venting/Flaring Preliminary Analysis
Division Information
Colorado Department of Public Health and Environment
Air Pollution Control Division
Equipment Description
This source vents natural gas from:
a well head separator
Emissions from this source are:
routed to an enclosed flare
Natural gas venting from a well head separator. Emissions from this source are routed to an enclosed flare.
Emission Calculation Method
EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3)
Ex=Q*MW "Xx /C
Ex = emissions of pollutant x
Q = Volumetric flow rate/volume of gas processed
MW = Molecular weight of gas = SG of gas * MW of air
Xx = mass fraction of x in gas
C = molar volume of ideal gas (379 scf/Ib-mol) at 60F and 1 atm
Gas/oil ratio
liquid throughput
Throughput
total downtime of compressor
11.838 scf/gal
91250 bbl
3832500 gal
45369135 scf
45.369135 MMscf
5%
Throughput (O)
MW
2.27 MMscf/yr
41.070 Ib/Ib-mol
259.0 scf/hr
0.000 MMscf/d
0.19 MMscf/mo
mole %
MW
Ibxllbmol
mass fraction
E
lb/hr
lb/yr
Helium
0.01
4.0026
0.000
0.000
Helium
0.0
2
CO2
1.294
44.01
0.569
0.014
CO2
0.4
3409
N2
0.066
28.013
0.018
0.000
N2
0.0
111
methane
18.884
16.041
3.029
0.074
methane
2.1
18131
ethane
21.325
30.063
6.411
0.156
ethane
4.4
38372
propane
36.575
44.092
16.1266
0.393
propane
11.0
96524
isobutane
4.112
58.118
2.3898
0.058
isobutane
1.6
14304
n -butane
11.761
58.118
6.8353
0.166
n -butane
4.7
40912
isopentane
2.044
72.114
1.4740
0.036
isopentane
1.0
8823
n -pentane
2.297
72.114
1.6565
0.040
n -pentane
1.1
9915
cyclopentane
0.335
70.13
0.2349
0.006
cyclopentane
0.2
1406
n -Hexane
0.3200
86.18
0.2758
0.007
n -Hexane
0.2
1651
cyclohexane
0.0830
84.16
0.0699
0.002
cyclohexane
0.0
418
Other hexanes
0.051
86.18
0.0440
0.001
Other hexanes
0.0
263
heptanes
0.131
100.21
0.1313
0.003
heptanes
0.1
786
methylcyclohexane
0.062
98.19
0.0609
0.001
methylcyclohexane
0.0
364
224-TMP
0.007
114.23
0.0080
0.000
224-TMP
0.0
48
Benzene
0.096
78.12
0.0750
0.002
Benzene
0.1
449
Toluene
0.039
92.15
0.0359
0.001
Toluene
0.0
215
Produced Natural Gas Venting/Flaring Preliminary Analysis
Colorado Department of Public Health and Environment
Air Pollution Control Division
Ethylbenzene
0.012
106.17
0.0127
0.000
Ethylbenzene
0.0
76
Xylenes
0.02
106.17
0.0212
0.001
Xylenes
0.0
127
C8+ Heavies
0.016
9935.897
1.5897
0.039
C8+ Heavies
1.1
9515
mass traction:
41.070
.7558
Notes
Mole %, MW, and mass fractions from Critter Creek 2-03H gas analysis collected XX/X/XX.
Emissions are based on 8760 hours of operation per year.
I calculated the average MW of C8+ based on the average MW on the analysis for the gas.
Total VOC Emissions (Uncontrolled)
annual limit assuming 95% control
monthly limit assuming 95% control (lb/mo.)
Flaring Information
Equipment Description
Flare to combust low-pressure separator gas during VRU downtime.
Cimmarron Energy
Manufacturer
Model
Serial Number
Gas Heating Value
Throughput
Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment
Air Pollution Control Division
ECD-2-48-210
2291
5197.034414
Btu/scf
MMBtu/yr
Combustion emission factor source: AP -42: Chapter 13.5
0.068
lb NOX/MMBtu
tpy NOX
0.37
0.96
lb CO/MMBtu
tpy CO
0.18
Emissions Summary
0.2
tpy NOX
Uncontrolled/PTE
1.0
tpy CO
92.9
tpy VOC
Controlled
4.6
tpy VOC
Uncontrolled
Total (lb/yr)
Scenario A
Reportable?
Controlled Total
(lb/yr)
Benzene
449
23
Yes
22
Toluene
215
11
No
11
Ethylbenzene
76
4
No
4
Xylenes
127
7
No
6
n -hexane
1651
83
Yes
83
224-TMP
48
3
No
2
Regulatory Applicability
AQCC Regulation 1 _
This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless
flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any
air pollutant which is in excess of 30% opacity.'
AQCC Regulation 2 _
Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of
odorous air contaminants from any single source such as to result in detectable odors which are measured in
excess of the following limits: For areas used predominantly for residential or commercial purposes it is a
violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free
air."
AQCC Regulation 3
Part A:
An APEN is required for this source because uncontrolled VOC emissions exceed two tons
per year in an attainment area.
Part B:
A permit is required for this source because uncontrolled VOC emissions from this facility
exceed five tons per year in an attainment area.
This source is subject to Section III.D.2 (Minor Source RACT) because it is located in a
nonattainment area. RACT for this source has been determined to be the use of a flare to
control emissions.
Is public comment
required?
Public Comment Required
AQCC Regulation 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
yes
This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVII.B.2
Facility Status
This facility is a synthetic minor source of NOXNOC/CO/HAP for Title V applicability.
This facility is a synthetic minor source of NOXNOC/CO/HAP for NSR applicability.
Produced Natural Gas Venting/Flaring Preliminary Analysis
tpy
0.00
1.70
0.06
9.07
19.19
48.26
7.15
20.46
4.41
4.96
0.70
0.83
0.21
0.13
0.39
0.18
0.02
0.22
0.11
Colorado Department of Public Health and Environment
Air Pollution Control Division
Produced Natural Gas Venting/Flaring Preliminary Analysis
0.04
0.06
4.76
92.9
4.6
789.0
Colorado Department of Public Health and Environment
Air Pollution Control Division
Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment
Air Pollution Control Division
005 One (1) above ground 400 bbl produced water storage tank
Emissions Calculations
Requsted Throughput
14600
bbl
Control
Flare
Efficiency
95.00%
Emissions Summary Table
Pollutant
Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
0.262
lb/bbl
1.9126
tpy
0.09563
tpy
CDPHE
Benzene
0.007
lb/bbl
102.2
lb/yr
5.11
lb/yr
CDPHE
n -Hexane
0.022
lb/bbl
321.2
lb/yr
16.06
lb/yr
CDPHE
Regulatory Review
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a
source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess
of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second
intervals for six minutes. The approved reference test method for visible emissions measurement is
EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of
this regulation.
Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator
of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions
into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods
aggregating more than six minutes in any sixty consecutive minutes. (only needed if using flare)
Regulation 2 - Odor
Section I.A - No person, wherever located, shall cause or allow the emission of odorous air
contaminants from any single source such as to result in detectable odors which are measured in
excess of the following limits: For areas used predominantly for residential or commercial purposes it
is a violation if odors are detected after the odorous air has been diluted with seven (7) or more
volumes of odor free air.
COLORADO DEPARTMENT OF PUBLIC HEALTH ENVIRONMENT
AIR POLUTION CONTROL DIVISION
INVENTORY
AIRS (County/Plant) //
Permit No. 0
Date 1/0/1900
Point #
Seg *
SCC
Pollutant or CAS
Fug
Dust
Uncontrolled Emission
Factor
Emisison Factor Source
Controlled
Actual
Emissions
(tpy)*
Controlled
Requested
Emissions
(tpy)'
PTE (tpy)*
Ctrl.
Eff%
NCRP =
reportable
?
0
31000205
NOx
n
155.788 lb/MMscf
AP -42: Chapter 13.5
0.2
0.2
0%
CO
n
847.67 lb/MMscf
AP -42: Chapter 13.5
1.0
1.0
0%
VOC
n
81903.71 lb/MMscf
Engineering Calcs
4.6
92.9
95%
71432
Benzene
n
197.8765 lb/MMscf
Engineering Calcs
22
449
95%
Yes
108883
Toluene
n
94.8245 lb/MMscf
Engineering Calcs
11
215
95%
No
100414
Ethylbenzene
n
33.6158 lb/MMscf
Engineering Calcs
4
76
95%
No
1330207
Xylene
n
56.0264 lb/MMscf
Engineering Calcs
6
127
95%
No
110543
n -Hexane
n
727.6412 lb/MMscf
Engineering Calcs
83
1651
95%
Yes
540841
224-TMP
n
21.0979 lb/MMscf
Engineering Calcs
2
48
95%
No
NOTES
'Emissions of criteria are reported in tons/yr; emissions of NCRPs are in lb/yr.
POINT PERMIT Descriptior NOx VOC Fug VOC CO Reportable Total HAP: NOx
000 00xx0000 Produced r 0.426859 11.22081 2.322616 0.426859
Controlled Emissions
POINT PERMIT Descriptior Formaldeh Acetaldehy Benzene Acrolein Toluene Ethylbenze Xylene
000 00xx0000 Produced natural gas venting 54.21817 25.98192 9.210738 15.35123
Uncontrolled
POINT PERMIT Descriptior Formaldeh Acetaldehy Benzene Acrolein Toluene Ethylbenze Xylene
000 00xx0000 Produced natural gas venting 1084.363 519.6385 184.2148 307.0246
VOC Fug VOC CO Reportable Total HAPs
224.4162 2.322616
n -Hexane 2,2,4 -Trim( Methanol 1,3 -Butadiene
199.3737 5.780822
n -Hexane 2,2,4 -Trim( Methanol 1, 3 -Butadiene
3987.474 115.6164
STATE OF COLORADO
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303) 692-3150
PERMIT NO: 16WE0767
DATE ISSUED:
ISSUED TO:
CONSTRUCTION PERMIT
Verdad Oil and Gas Company
Issuance 1
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Oil and gas facility, known as the Highland 29-1N, located in SWNE Sec 29 T1 N R65W, in
Weld County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Facility
Equipment ID
AIRS
Point
Description
Compressor
001
One (1) General Motors, Model FX 10Q, Serial Number
10CHMM502250021, natural gas -fired, naturally aspirated,
4SRB reciprocating internal combustion engine, site rated at
92 horsepower. non -selective catalytic reduction (NSCR)
system and air -fuel ratio control This emission unit is used
for natural gas compression.
Condensate
Storage Tanks
003
Three (3) 400 barrels manifolded together used to store
condensate.
Condensate
Loading
004
Loadout of condensate into tank trucks
Separator
Venting
005
Produced gas vented from separators during compressor
downtime.
Point 001: This engine may be replaced with another engine in accordance with the
temporary engine replacement provision or with another General Motors FX 10Q engine in
accordance with the permanent replacement provision of the Alternate Operating Scenario
(AOS), included in this permit as Attachment A.
THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO
AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND
CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS
INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
AIRS ID: 123/9E95/001
Page 1 of 18
NGEngine Version 2014-1
Public Health and Environment
Air Pollution Control Division
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than
fifteen days of the latter of commencement of operation or issuance of this permit,
by submitting a Notice of Startup form to the Division. The Notice of Startup form
may be downloaded online at https://www.colorado.00v/pacific/cdphe/other-air-
permittinq-notices. Failure to notify the Division of startup of the permitted source is a
violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section
III.G.1 and can result in the revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit shall be
demonstrated to the Division. It is the owner or operator's responsibility to self -certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may
result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2).
3. This permit shall expire if the owner or operator of the source for which this permit was
issued: (i) does not commence construction/modification or operation of this source
within 18 months after either, the date of issuance of this construction permit or the date
on which such construction or activity was scheduled to commence as set forth in the
permit application associated with this permit; (ii) discontinues construction for a period
of eighteen months or more; (iii) does not complete construction within a reasonable
time of the estimated completion date. The Division may grant extensions of the
deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B,
III.F.4.)
4. The operator shall retain the permit final authorization letter issued by the Division after
completion of self -certification, with the most current construction permit. This
construction permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
5. Emissions of air pollutants shall not exceed the following limitations (as calculated in the
Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4)
Annual Limits:
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission Type
NO,
vOC
CO
Compressor
001
0.9
0.6
1.8
Point
Condensate
Storage Tanks
003
19.2
Point
Condensate
Loading
004
7.97
Point
Separators
005
0.2
4.6
1.0
Point
ee "Notes to Permit Holder" for information on emission factors and methods used to calculate
limits.
Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0
tpy.
Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy.
AIRS ID: 123/9E95/001
Page 2 of 18
Public Health and Environment
Air Pollution Control Division
Compliance with the annual limits shall be determined on a rolling twelve (12) month
total. By the end of each month a new twelve month total is calculated based on the
previous twelve months' data. The permit holder shall calculate emissions each month
and keep a compliance record on site or at a local field office with site responsibility for
Division review.
Compliance with the annual limits shall be determined by recording the facility's annual
criteria pollutant emissions, (including all HAPs above the de-minimis reporting level)
from each emission unit, on a rolling twelve (12) month total. By the end of each month
a new twelve-month total shall be calculated based on the previous twelve months' data.
The permit holder shall calculate emissions each month and keep a compliance record
on site or at a local field office with site responsibility, for Division review. This rolling
twelve-month total shall apply to all permitted emission units, requiring an APEN, at this
facility.
6. The emission points in the table below shall be operated and maintained with the control
equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit (Reference: Regulation No.3, Part B, Section III.E.)
Facility
Equipment ID
AIRS
Point
Control Device
Pollutants
Controlled
Compressor
001
Catalytic Reduction and Air to Fuel Ratio
Controller
NOx, CO
Condensate
Storage
Tanks
003
Enclosed Flare
VOC, HAPs
Separators
005
Enclosed Flare
VOC, HAPs
PROCESS LIMITATIONS AND RECORDS
7. This source shall be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rate shall be maintained by the owner or
operator and made available to the Division for inspection upon request. (Reference:
Regulation 3, Part B, II.A.4)
Process/Consumption Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Compressor
001
Consumption of natural gas as a
fuel
7.21 MMscf/yr
Condensate
Storage
Tanks
003
Condensate
91,250 bbl/yr
Condensate
Loading
004
Condensate Loadout
109,500 bbl/yr
AIRS ID: 123/9E95/001
Page 3 of 18
Public Health and Environment
Air Pollution Control Division
Produced gas vented from
Separators
005
separators during compressor
downtime
2.3 MMscf/yr
Fuel consumption shall be measured by one of the following methods: individual engine
fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of
operation; or manufacturer -provided fuel consumption rate.
The owner or operator shall calculate monthly process rates based on the calendar
month.
Produced gas vented from separators during downtime will be measured by using a
cubic feet of gas to gallon of liquid ratio of 11.838 and tracking liquid throughputs during
compressor downtime
Compliance with the annual throughput limits shall be determined on a rolling twelve (12)
month total. By the end of each month a new twelve-month total is calculated based on
the previous twelve months' data. The permit holder shall calculate throughput each
month and keep a compliance record on site or at a local field office with site
responsibility, for Division review.
8. Point 004: Condensate loading to truck tanks shall be conducted by submerged fill.
(Reference: Regulation 3, Part B, III.E)
9. Point 005: The owner or operator must use monthly VRU downtime records, monthly
condensate/crude oil throughput records, calculation methods detailed in the O&M Plan,
and the emission factors established in the Notes to Permit Holder to demonstrate
compliance with the process and emissions limits specified in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
10. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on
the subject equipment for ease of identification. (Reference: Regulation Number 3, Part
B, III.E.) (State only enforceable)
11. Point 001: Visible emissions shall not exceed twenty percent (20%) opacity during
normal operation of the source. During periods of startup, process modification, or
adjustment of control equipment visible emissions shall not exceed 30% opacity for more
than six minutes in any sixty consecutive minutes. Emission control devices subject to
Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions.
(Reference: Regulation No. 1, Section I I.A.1. & 4.)
12. This source is subject to the odor requirements of Regulation No. 2. (State only
enforceable)
13. Point 003: This source is subject to Regulation Number 7, Section XII. The operator
shall comply with all applicable requirements of Section XII and, specifically, shall:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for condensate storage tanks; and
• Ensure that the combustion device controlling emissions from this storage tank
be enclosed, have no visible emissions, and be designed so that an observer
can, by means of visual observation from the outside of the enclosed combustion
AIRS ID: 123/9E95/001 Page 4 of 18
Public Health and Environment
Air Pollution Control Division
device, or by other means approved by the Division, determine whether it is
operating properly. (Regulation Number 7, Section XII.C.) (State only
enforceable)
14. Point 003 and 005: The combustion device covered by this permit is subject to
Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a
flare or other combustion device is used to control emissions of volatile organic
compounds to comply with Section XVII, it shall be enclosed; have no visible emissions
during normal operations, as defined under Regulation Number 7, XVII.A.16; and be
designed so that an observer can, by means of visual observation from the outside of
the enclosed flare or combustion device, or by other convenient means approved by the
Division, determine whether it is operating properly. This flare must be equipped with an
operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with
an operational auto -igniter upon installation of the combustion device;
• All combustion devices installed before May 1, 2014, must be equipped with an
operational auto -igniter by or before May 1, 2016, or after the next combustion
device planned shutdown, whichever comes first.
15. Point 003: The storage tank covered by this permit is subject to the emission control
requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall
install and operate air pollution control equipment that achieves an average hydrocarbon
control efficiency of 95%. If a combustion device is used, it must have a design
destruction efficiency of at least 98% for hydrocarbons except where the combustion
device has been authorized by permit prior to May 1, 2014. The source shall follow the
inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain
records of the inspections for a period of two years, made available to the Division upon
request. This control requirement must be met within 90 days of the date that the
storage tank commences operation.
16. Point 003: The storage tanks covered by this permit are subject to the venting and
Storage Tank Emission Management System ("STEM") requirements of Regulation
Number 7, Section XVII.C.2.
17. Point 004: This source is located in an ozone non -attainment or attainment -
maintenance area and is subject to the Reasonably Available Control Technology
(RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to
truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E)
18. Point 004: The owner or operator shall follow loading procedures that minimize the
leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation
3, Part B, I I I. D.2):
a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking,
or other liquid or vapor loss during loading and unloading.
b. All compartment hatches at the facility (including thief hatches) shall be closed
and latched at all times when loading operations are not active, except for
periods of maintenance, gauging, or safety of personnel and equipment.
AIRS ID: 123/9E95/001 Page 5 of 18
Public Health and Environment
Air Pollution Control Division
c. The owner or operator shall inspect onsite loading equipment during loading
operations to monitor compliance with above conditions. The inspections shall
occur at least monthly. Each inspection shall be documented in a log available
to the Division on request.
19. Point 004: All hydrocarbon liquid loading operations, regardless of size, shall be
designed, operated and maintained so as to minimize leakage of volatile organic
compounds to the atmosphere to the maximum extent practicable.
OPERATING & MAINTENANCE REQUIREMENTS
20. Upon startup of these points, the owner or operator shall follow the most recent
operating and maintenance (O&M) plan and record keeping format approved by the
Division, in order to demonstrate compliance on an ongoing basis with the requirements
of this permit. Revisions to your O&M plan are subject to Division approval prior to
implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
21. Point 001: A source initial compliance test shall be conducted on emissions point 001 to
measure the emission rate(s) for the pollutants listed below in order to demonstrate
compliance with the emission limits in this permit. The test protocol must be in
accordance with the requirements of the Air Pollution Control Division Compliance Test
Manual and shall be submitted to the Division for review and approval at least thirty (30)
days prior to testing. No compliance test shall be conducted without prior approval from
the Division. Any compliance test conducted to show compliance with a monthly or
annual emission limitation shall have the results projected up to the monthly or annual
averaging time by multiplying the test results by the allowable number of operating hours
for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3)
Oxides of Nitrogen using EPA approved methods.
Carbon Monoxide using EPA approved methods.
Volatile Organic Compounds using EPA approved methods.
Hazardous Air Pollutants using EPA approved methods.
22. Point 003 and 005: The owner or operator shall demonstrate compliance with opacity
standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to
determine the presence or absence of visible emissions. "Visible Emissions" means
observations of smoke for any period or periods of duration greater than or equal to one
minute in any fifteen minute period during normal operation. (Regulation Number 7,
Sections XII.C, XVII.B.2. and XVII.A.16)
Periodic Testing Requirements
23. Point 001: This engine is subject to the periodic testing requirements as specified in the
operating and maintenance (O&M) plan as approved by the Division. Revisions to your
O&M plan are subject to Division approval. Replacements of this unit completed as
Alternative Operating Scenarios may be subject to additional testing requirements as
specified in Attachment A.
AIRS ID: 123/9E95/001 Page 6 of 18
Public Health and Environment
Air Pollution Control Division
24. Point 003 and 005: The owner or operator shall demonstrate compliance with opacity
standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, on a
weekly basis to determine the presence or absence of visible emissions. "Visible
Emissions" means observations of smoke for any period or periods of duration greater
than or equal to one minute in any fifteen minute period during normal operation.
(Regulation Number 7, Sections XII.C, XVIl.B.2. and XVII.A.16)
ADDITIONAL REQUIREMENTS
25. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation
No. 3, Part A, II.C)
a. Annually by April 30th whenever a significant increase in emissions occurs as
follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions
of five (5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in
ozone nonattainment areas emitting less than 100 tons of VOC or NO, per
year, a change in annual actual emissions of one (1) ton per year or more or five
percent, whichever is greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions
of five percent or 50 tons per year or more, whichever is less, above the level
reported on the last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less,
above the level reported on the last APEN submitted to the Division.
b. Whenever there is a change in the owner or operator of any facility, process, or
activity; or
c. Whenever new control equipment is installed, or whenever a different type of
control equipment replaces an existing type of control equipment; or
d. Whenever a permit limitation must be modified; or
e. No later than 30 days before the existing APEN expires.
f. Within 14 calendar days of commencing operation of a permanent replacement
engine under the alternative operating scenario outlined in this permit as
Attachment A. The APEN shall include the specific manufacturer, model and
serial number and horsepower of the permanent replacement engine, the
appropriate APEN filing fee and a cover letter explaining that the owner or
operator is exercising an alternative -operating scenario and is installing a
permanent replacement engine.
26. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source
at any such time that this source becomes major solely by virtue of a relaxation in any
permit condition. Any relaxation that increases the potential to emit above the applicable
Federal program threshold will require a full review of the source as though construction
had not yet commenced on the source. The source shall not exceed the Federal
program threshold until a permit is granted. (Regulation No. 3 Part D).
AIRS ID: 123/9E95/001 Page 7 of 18
Public Health and Environment
Air Pollution Control Division
GENERAL TERMS AND CONDITIONS
27. This permit and any attachments must be retained and made available for inspection
upon request. The permit may be reissued to a new owner by the APCD as provided in
AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership
and the submittal of a revised APEN and the required fee.
28. If this permit specifically states that final authorization has been granted, then the
remainder of this condition is not applicable. Otherwise, the issuance of this construction
permit does not provide "final" authority for this activity or operation of this source. Final
authorization of the permit must be secured from the APCD in writing in accordance with
the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section
III.G. Final authorization cannot be granted until the operation or activity commences
and has been verified by the APCD as conforming in all respects with the conditions of
the permit. Once self -certification of all points has been reviewed and approved by the
Division, it will provide written documentation of such final authorization. Details for
obtaining final authorization to operate are located in the Requirements to Self -
Certify for Final Authorization section of this permit.
29. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the owner or operator and is conditioned upon conduct of the activity, or
construction, installation and operation of the source, in accordance with this information
and with representations made by the owner or operator or owner or operator's agents.
It is valid only for the equipment and operations or activity specifically identified on the
permit.
30. Unless specifically stated otherwise, the general and specific conditions contained in this
permit have been determined by the APCD to be necessary to assure compliance with
the provisions of Section 25-7-114.5(7)(a), C.R.S.
31. Each and every condition of this permit is a material part hereof and is not severable.
Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire
permit and upon such occurrence, this permit shall be deemed denied ab initio. This
permit may be revoked at any time prior to self -certification and final authorization by the
Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality
Control Act and regulations of the Air Quality Control Commission (AQCC), including
failure to meet any express term or condition of the permit. If the Division denies a
permit, conditions imposed upon a permit are contested by the owner or operator, or the
Division revokes a permit, the owner or operator of a source may request a hearing
before the AQCC for review of the Division's action.
32. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution
Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and
administration. If a source or activity is to be discontinued, the owner must notify the
Division in writing requesting a cancellation of the permit. Upon notification, annual fee
billing will terminate.
33. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution
Prevention and Control Act or the regulations of the AQCC may result in administrative,
civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121
(injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S.
AIRS ID: 123/9E95/001 Page 8 of 18
Public Health and Environment
Air Pollution Control Division
By:
David Thompson
Permit Engineer
Permit Histo
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Verdad Oil and Gas Corporation.
AIRS ID: 123/9E95/001 Page 9 of 18
Public Health and Environment
Air Pollution Control Division
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these
fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of
receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference:
Regulation No. 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN)
and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written notice
to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process
limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis
of the specific compounds emitted if the source(s) operate at the permitted limitations.
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emission
Rate
(lb/yr)
Are the
emissions
reportable?
Controlled
Emission
Rate (Ib/yr)
001
Formaldehyde
50000
140
No
140
Methanol
67561
21
No
21
Acetaldehyde
75070
19
No
19
Acrolein
107028
18
No
18
Benzene
71432
11
No
11
1,3 -Butadiene
106990
5
No
5
Toluene
108883
4
No
4
003
Benzene
71432
2128
Yes
107
n -Hexane
110543
11142
Yes
558
004
Benzene
71432
55
No
55
n -Hexane
110543
299
No
299
005
Benzene
71432
1084
Yes
54
Toluene
108883
520
Yes
26
Ethylbenzene
100414
184
No
9
Xylenes
1330207
307
Yes
15
n -hexane
110543
3987
Yes
199
224-TMP
540841
116
No
6
AIRS ID: 123/9E95/001
Page 10 of 18
Public Health and Environment
Air Pollution Control Division
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
CAS
Pollutant
Emission
Uncontrolled
lb/MMBtu
Factors -
g/bhp-hr
Emission
Controlled
Ib/MMBtu
Factors —
g/bhp-hr
NOx
3.6311
14.00
0.2542
0.98
CO
2.8530
11.00
0.5135
1.98
VOC
0.1816
0.70
0.1816
0.70
50000
Formaldehyde
0.0205
0.08
0.0205
0.08
67561
Methanol
0.0031
0.01
0.0031
0.01
75070
Acetaldehyde
0.0028
0.01
0.0028
0.01
107028
Acrolein
0.0026
0.01
0.0026
0.01
71432
Benzene
0.0016
0.01
0.0016
0.01
106990
1,3 -Butadiene
0.0007
0.00
0.0007
0.00
108883
Toluene
0.0006
0.00
0.0006
0.00
Emission factors are based on a Brake-Specfic Fuel Consumption Factor of 8500 Btu/hp-hr, a
site -rated horsepower value of 92, and a fuel heat value of 950.25 Btu/scf.
Emission Factor Sources:
CAS
Pollutant
Uncontrolled EFSource
Controlled EF Source
NOx
Manufacturer
Manufacturer
CO
Manufacturer
Manufacturer
VOC
Manufacturer
Manufacturer
50000
Formaldehyde
0
67561
Methanol
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
75070
Acetaldehyde
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
107028
Acrolein
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
71432
Benzene
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
106990
1,3 -Butadiene
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
108883
Toluene
AP -42; Table 3.2-3 (7/2000);
Natural Gas
No Control
Point 003:
Pollutant
Emission Factors
Uncontrolled
Source
lb/bbl Condensate
Throughput
VOC
8.41
E&P TANK
n -Hexane
0.024
E&P TANK
Benzene
0.1221
E&P TANK
Note: The controlled emissions for this point are based on the flare control efficiency of 95%.
Point 004:
Pollutant
Emission Factors
Uncontrolled
lb/bbl loaded
-
Source
VOC
0.146
AP -42
AIRS ID: 123/9E95/001
Page 11 of 18
Pollutant
Emission Factors
Uncontrolled
Ib/bbl loaded
-
Source
Benzene
0.0005
PS 14-02
n -Hexane
0.0027
PS 14-02
Public Health and Environment
Air Pollution Control Division
The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1
(version 1/95) using the following values:
L = 12.46" S" P" M/T
S = 0.6 (Submerged loading: dedicated normal service)
P (true vapor pressure) = 5.8692 psia
M (vapor molecular weight) = 41.07 lb/lb-mol
T (temperature of liquid loaded) = 520 °R
Point 005:
CAS #
Pollutant
Uncontrolled
Emission Factors
(lb/MMSCF)
Controlled
Emission Factors
(lb/MMSCF)
Source
VOC
81904
4095.186
Gas Analysis
71432
Benzene
197.877
9.894
Gas Analysis
108883
Toluene
94.825
4.742
Gas Analysis
100414
Ethylbenzene
33.616
1.681
Gas Analysis
1330207
Xylene
56.027
2.802
Gas Analysis
110543
n -Hexane
727.640
36.383
Gas Analysis
540841
2'2'4
Trimethylpentane
21.098
1.055
Gas Analysis
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the
most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division at
(303)-692-3150.
7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for
Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register
posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality
Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA
website at: http://www.epa.dov/ttn/atw/area/fr18ia08.pdf
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC, HAPs
NANSR
Synthetic Minor Source of: VOC, HAPs
MACT ZZZZ
Major Source Requirements: Not Applicable
Area Source Requirements: Applicable
AIRS ID: 123/9E95/001
Page 12 of 18
Public Health and Environment
Air Pollution Control Division
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A — Subpart KKKK
NSPS
Part 60, Appendixes
Appendix A — Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT
63.1-63.599
Subpart A — Subpart Z
MACT
63.600-63.1199
Subpart AA — Subpart DDD
MACT
63.1200-63.1439
Subpart EEE — Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ — Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ — Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN — Subpart XXXXXX
10) A self certification form and guidance on how to self -certify compliance as required by this permit may
be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification
AIRS ID: 123/9E95/001 Page 13 of 18
Public Health and Environment
Air Pollution Control Division
ATTACHMENT A:
ALTERNATIVE OPERATING SCENARIOS
RECIPROCATING INTERNAL COMBUSTION ENGINES
October 12, 2012
2. Alternative Operating Scenarios
The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of
natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the
requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating
Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary
Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all
applicable substantive and procedural requirements. This permit incorporates and shall be considered a
Construction Permit for any engine replacement performed in accordance with this AOS, and the owner
or operator shall be allowed to perform such engine replacement without applying for a revision to this
permit or obtaining a new Construction Permit.
2.1 Engine Replacement
The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown
or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a
temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90
operating days or less in any 12 month period. "Permanent" is defined as in the same service for more
than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is
in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90
day total. The compliance demonstrations and any periodic monitoring required by this AOS are in
addition to any compliance demonstrations or periodic monitoring required by this permit.
All replacement engines are subject to all federally applicable and state -only requirements set forth in this
permit (including monitoring and record keeping).
The results of all tests and the associated calculations required by this AOS shall be submitted to the
Division within 30 calendar days of the test or within 60 days of the test if such testing is required to
demonstrate compliance with NSPS or MACT requirements.
Results of all tests shall be kept on site for five (5) years and made available to the Division upon request.
The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date
of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and
serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer,
model number, horsepower, and serial number of the replacement engine. In addition to the log, the
owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make
them available to the Division upon request.
2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to
the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and
horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying
this permit, so long as the temporary replacement engine complies with all permit limitations and other
requirements applicable to the existing engine. Measurement of emissions from the temporary
replacement engine shall be made as set forth in section 2.2.
AIRS ID: 123/9E95/001 Page 14 of 18
Public Health and Environment
Air Pollution Control Division
2.1.2 The owner or operator may permanently replace the existing compressor engine with another
engine with the same manufacturer, model, and horsepower engines without modifying this permit so
long as the permanent replacement engine complies with all permit limitations and other requirements
applicable to the existing engine as well as any new applicable requirements for the replacement engine.
Measurement of emissions from the permanent replacement engine and compliance with the applicable
emission limitations shall be made as set forth in section 2.2.
An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial
number and horsepower of the permanent replacement engine shall be filed with the Division for the
permanent replacement engine within 14 calendar days of commencing operation of the replacement
engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that
the owner or operator is exercising an alternative operating scenario and is installing a permanent
replacement engine, and a copy of the relevant Applicability Reports for the replacement engine.
Example Applicability
Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be
accompanied by a certification from the Responsible Official indicating that "based on the information and
belief formed after reasonable inquiry, the statements and information included in the submittal are true,
accurate and complete".
This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine
or an engine that is not subject to emission limits.
The owner or operator shall agree to pay fees based on the normal permit processing rate for review of
information submitted to the Division in regard to any permanent engine replacement.
2.2 Portable Analyzer Testing
Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping
Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss
streamlining the testing requirements.
Note that the testing required by this Condition may be used to satisfy the periodic testing requirements
specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer
testing, this test conducted under the AOS will serve as the quarterly test and an additional portable
analyzer test is not required for another three months).
The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required
by this Condition, if approved in advance by the Division.
The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the
exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of
commencing operation of the replacement engine.
All portable analyzer testing required by this permit shall be conducted using the Division's Portable
Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at:
https://www.colorado.ciov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit.
For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the
tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or
year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation
the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever
applies.
AIRS ID: 123/9E951001 Page 15 of 18
Public Health and Environment
Air Pollution Control Division
For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or
concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement
engine will be subject to, the results of the test shall be converted to the appropriate units as described in
the above -mentioned Portable Analyzer Monitoring Protocol document.
If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the
absence of credible evidence to the contrary, the source may certify that the engine is in compliance with
both the NOX and CO emission limitations for the relevant time period.
Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if
the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission
limitations, the engine will be considered to be out of compliance from the date of the portable analyzer
test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or
until the engine is taken offline.
2.3 Applicable Regulations for Permanent Engine Replacements
2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2
All permanent replacement engines that are located in an area that is classified as
attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT)
for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and
NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which
the area is in attainment/maintenance or nonattainment, except as follows:
In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of
emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds
40 tons/yr.
For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating
internal combustion engines:
VOC: The emission limitations in NSPS JJJJ
CO: The emission limitations in NSPS JJJJ
NOX: The emission limitations in NSPS JJJJ
SO2: Use of natural gas as fuel
PM10: Use of natural gas as fuel
As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains
20.0 grains or less of total sulfur per 100 standard cubic feet.
2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -
Only conditions).
Control Requirements: Section XVI
Any permanent replacement engine located within the boundaries of an ozone nonattainment area is
subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified
below:
Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-
selective catalyst and air fuel controller to reduce emission.
Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation
catalyst to reduce emissions.
AIRS ID: 123/9E95/001 Page 16 of 18
Public Health and Environment
Air Pollution Control Division
The above emission control equipment shall be appropriately sized for the engine and shall be operated
and maintained according to manufacturer specifications.
The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2.
Emission Standards: Section XVII. E — State -only requirements
Any permanent engine that is either constructed or relocated to the state of Colorado from another state,
after the date listed in the table below shall operate and maintain each engine according to the
manufacturer's written instructions or procedures to the extent practicable and consistent with
technological limitations and good engineering and maintenance practices over the entire life of the
engine so that it achieves the emission standards required in the table below:
Max Engine HP
Construction or
Relocation Date
Emission Standards in G/hp-hr
NOx
CO
VOC
100<Hp<500
January 1, 2008
January 1, 2011
2.0
1.0
4.0
2.0
1.0
0.7
500≤Hp
July 1, 2007
July 1, 2010
2.0
1.0
4.0
2.0
1.0
0.7
The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2.
2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ
A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater
than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp
except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for
lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements
of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting
requirements for the permanent engine replacement shall be included in the Applicability Reports
required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this
AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this
AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted
within the time frame specified in Condition 2.2.
Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from
outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to
the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes
equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ
requirements).
However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does,
any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ,
there will be an additional step added to the determination of the NSPS. Under the provisions of
Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the
State of Colorado into the State of Colorado is considered to be a new source, subject to the
requirements of NSPS JJJJ.
2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ
A permanent replacement engine located at either an area or major source is subject to the requirements
in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting
AIRS ID: 12319E951001 Page 17 of 18
Public Health and Environment
Air Pollution Control Division
requirements for the permanent engine replacement shall be included in the Applicability Reports
required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this
AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under
Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time
frame specified in Condition 2.2.
2.4 Additional Sources
The replacement of an existing engine with a new engine is viewed by the Division as the installation of a
new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an
advanced construction permit review. The AOS cannot be used for additional new emission points for any
site; an engine that is being installed as an entirely new emission point and not as part of an AOS-
approved replacement of an existing onsite engine has to go through the appropriate
Construction/Operating permitting process prior to installation.
AIRS ID: 12319E951001 Page 18 of 18
a.)
.5
Internal Combustion En
Compressor
Section 02 — Requested Action (check applicable request boxes)
Section 01— Administrative Information
Request for NEW permit or newly reported emission source
O
UU
U
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Verdad Oil and Gas Corporation
Highland 29-1 N
County: Weld
SWNE S29 Ti N R65W
d d e
❑ ❑
Change fuel or equipment
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a
u
Elevation: 5,013
Change permit limit
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❑ ❑
ZIP Code: 75235
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AP -42, E&P Tanks
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Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above.
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Vented Gas Properties: 41.07
Submit a representative gas analysis (in(
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FORM APCD-211
AIR POLLUTANT EMISSION NOTICE (ADEN) & Application for Construction Permit — Natural Gas Ventin
Emission Source AIRS 1D:
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Permit Number:
\
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00 2
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Section 06 —Stack (Source, if no combustion) Location (Datum & either Let/Long or UTM)
must be liste
-104.691685
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let (check one
Exhaust Opening Shape & Size (check
Section 07 — Control Device Information
Section 08 — Emissions Inventory Information & Emission Control Information
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Estimation
Method or
Emission
Factor Source
Site Specific II
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AP -42 II
No S in Gas
'l ,l. Site Specific
1 i — i Site Specific
-- _ "16. If Site Specific
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Requested Permitted Emissions
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Ethylhenzene ECD 100 95 `3�i-� lb/MMscf --
Xylem ECD 100 95 'A- I Ib/MMscf __
n -Hexane ECD 100 95 '12.1 G. lb/MMscf —
Emission Factor
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Control Device Description
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FormAPCD-2I I-NaturalGasVentingAPEN-Ver.10-14-2013 docx
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FORM APCD-211
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