HomeMy WebLinkAbout20191579.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
1150 0 St
PO Box 758
Greeley, CO 80632
April 15, 2019
Dear Sir or Madam:
RECEIVED
APR 2 2 2019
WELD COUNTY
COMMISSIONERS
On April 18, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Rocky
Mountain Midstream, LLC - Auburn Compressor Station. 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 I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
C.C. PIS:VP), NL(3 T),
pWA-SMIMC ticw>
4122/tcl
2019-1579.
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Rocky Mountain Midstream, LLC - Auburn Compressor Station - Weld County
Notice Period Begins: April 18, 2019
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: Rocky Mountain Midstream, LLC
Facility: Auburn Compressor Station
Natural gas compressor station
Section 26 T5N R65W
Weld County
The proposed project or activity is as follows: New compressor station in the ozone non -attainment area of
Weld County. Permitted equipment are two (2) TEG dehydration units, and an enclosed combustor to
control waste gases from those dehydration units. APEN-exempt equipment associated with this project are
reboilers for the TEG dehydrators, two 1000 -bbl slop tanks, truck loadout of slop, fugitive equipment leaks,
planned maintenance/startup/shutdown activities, compressor venting, pigging, and blowdowns
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 19WE0171 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. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Andy Gruel
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
ADD
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer: ':,Andy Gruel
Package #: 393474
Received Date: 2/15/2019
Review Start Date: 3/14/2019''
Section 01 - Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical
Address/Location:
County:
Type of Facility: Natural Gas CompressorStation
What industry segment? Oil & Natural Gas Production & Proce
Is this facility located in a NAAQS non -attainment area?
If yes, for what pollutant? ❑ Carbon Monoxide (CO)
Rocky Mountain Midstream, LLC',
123
A028
Auburn Compressor Station '-z2
Section 26, Township SN, Range 65W
Weld County
Section 02 - Emissions Units In Permit Application
Yes
Particulate Matter (PM)
Quadrant
Section
Township
Range
26
5N
65
Ozone (NOx & VOC)
AIRs Point #
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Process Flare
CS
- Yes
19WE0171.
CP1
Yes
Permit initial
uance
Controls dehys
002.
.. Dehydrator r
- 01
003
:: `.17 hydretor.:i�, :.
D2
004
Natural Gas IVCC
TBD -- GP02 Application to be submitted after 19WE0170 issuance
005
Natural Gas RICE
TBD -- GP02 Application to be submitted after 19WE0170 issuance
006
Nfatural Gas RICE
TED -- GP02 Application to be submitted after 19WE0170 issuance
Section 03 - Description of Project
New compressor station in the ozone non -attainment area of Weld County. APEN-exempt equipment associated with this project are reboilers for the TEG dehydrators, two
1000 bbl slop tanks, truck loadout of slop, fugitive equipment leaks, planned maintenance/startup/shutdown activities, compressor venting, pigging, and blowdowns.
The project includes threeCaterpillar G3608 compression engines, but the applicant has not yet submitted the GP02 requests for those because the serial number is not
available. The NOx emissions from those three engines put the facility permitted emissions very close to the threshold to require ambient air monitoring for NOx (40 tpy),
and the applicant has been notifiedthat if those GP02 applications push the site over 40 tpy NOx then the permit for 19WE0170 may be revoked until modeling analysis can
be completed. ,
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why? RequestingSynthetic Minor P
Section 05 - Ambient Air Impact Analysis Requirement:
Was a quantitative modeling analysis required? No
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Yes
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
No, based on construction permit application. Forthcoming GP02 applications may cause the project to re,
modeling analysis.
No
Yes ... .'..
SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
Is this stationary source a major source? '..
If yes, explain what programs and which pollutants here SO2
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
No
NOx CO
J
J
VOC
LI
PM2.5 PM10 TSP HAPs
Combustor Emissions Inventory
001 Combustor
Facility AIRS ID:
123
County
A02B
Plant
001
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit Description: Enclosed combustor to control waste gas streams from two (2) 60 MMscfd TEG dehydrators (Point 002 and Point 003)
Emission Control Device Description: (Enclosed combustor (Lead EC48 2S 130-0035-000, so: T0D)
Requested Overall VOC & HAP Control Efficiency %: 98 This is the control efficiency for VOC and HAP at points 002 and 003. Emissions from this point
001 only include secondary emissions from that combustion.
Limited Process Parameter Waste gas + purge gas + pilot gas
Gas meter No, gas flow is calculated based on monthly GLYCaIc report for points 002 and 003 and based on actual gas throughput
Section 03- Processing Rate Information for Emissions Estimates
Secondary Emissions - Combustion of dehydrator waste gas
Pilot burners (2 @ 22 scfh each) 44 scfh
Purge fuel 4 scfh
48 scfh
Pilot + Purge
0.42 MMscf/yr
Waste Gas (total 2 dehys, flash+still)
2380 scfh
20.85 MMscf/yr
0.04 MMsd/month)
from Point 002 and Point 003; from GLYCaIc output
1.77 MMsd/month
Total (pilot + purges- waste)
Waste Gas LHV -,
Fuel (pilot and purge) LHV
Pilot and purge VOC %
Pilot and purge MW
Actual Throughput =
2428 scfh
1511 btu/scf
1,288 Btu/scf
17.23%
24.35 Ib/Ibmol
MMscf/yr
21.269 MMscf/yr
from Point 002 and Point 003; from GLYCaIc output
based on GLYCaIc dry gas stream
based on GLYCaIc dry gas stream
based on GLYCaIc dry gas stream
3.67 MMBtu/yr
Requested Permit Limit Throughput = 21.27 MMsc-f/yr
Requested Monthly Throughput = 1.81 MMscf per month
Potential to Emit (PTE) Throughput =
Section 04- Emissions Factors & Methodologies
Description
21,27 MMsd/yr
Emissions attributed to this equipment includes combustion emissions of NO; CO, PM, 5O2 associated with combustionof waste gas from TEG dehydrator associated with Paint 002 and Point 003 as well as pilot and purge
gasnecessary fo roper operation of the combustor, Emissions of VOC associated with uncombusted VOC in the dehydrator streams are accounted for with Point 002 and 003. Emissions of VOC reported below are only those '..
asso!cated with thecombustion of purge gas and pilot gas.
iu d
Pollutant
Primary Control Device
Emission Factor Source
Uncontrolled Uncontrolled
(Ib/MMBtu) Ib/MMsd
(Waste Heat
Combusted)
(Gas Throughput)
PM10
0.0075 LL
11.259
=` AP -42 Table 1:4-2 (PM10/Pt�!1
PM2.5
- 0.0075
11.259
a AP -42 Table 1.4-2 (rM10/R
ii
AP-421aEle 1.-t-2 (So
SOx
0.0006
0.889
NOx
0.1380
208.530
C Flare Erosions Guidance'
CO
r�' -X0.2755 ����� ��i,�4�16.304
��d✓1.4Wlaf.&I Jbi.Yi iiSs,
e RCCfi re niosions Guidance (Cii
/A- An ounte3far in Prorers 02 behz
VOC
Process 02 Combustion of "plot and purge fuel . ._
Primary Control Device
Uncontrolled Uncontrolled
Pollutant
(Ib/MMBtu) #REF!
Emission Factor Source
(Waste Heat
Combusted)
(Gas Throughput)
PM10
0.0075
9.597
".°AF -42 Table 1.4=2••(PM 20/PM.2.5)
PM2.5
0.0075
9.597
,- AP -42 Table 1,4-2 (PIVI10/P98„2.5Y
SOx0.0006
0,758
Av-42Tahie 2.4-7 (8Ox)
NOx
.0 .1380 't (.
177,744
7NRCC Elan. rml=sions G idance (NG
CO
:.0.2755
354.844
TNRCC Flare Emissions Guidance (CO)
VOC
221.107
..Mass balance at 98% DRE
Section OS - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month)
PM10
PM2.5
SOx
NOx
CO
VOC
0.12
0.12
0.12
20
0.12
0.12
0.12
20
0.01
0.01
0.01
2
2.21
2.21
2.21
376
4.41
4.41
4.41
750
0.05
0.05
0.05
8
2 of 9
K:\PA\2019\19 W E0171. CP1
Combustor Emissions Inventory
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, R 'Source requires a permit
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Requirements
#REF'
Using Gas Throughput to Monitor Compliance
Does the company use site specific emission factors based on a gal sample to estimate emissions?
This sample should represent the gas outlet of the equipment covered under this AIRs ID, and should have been collected within one year of the application received date. However, if
the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permit will contain: an "Initial Testing Requiremene to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor
analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Will the operator have a meter installed and operational upon startup of this point? No - N/A
Does the company request a control device efficient p y efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based
on inlet and outlet concentration sampling
Section 08 - Technical Analysis Notes
VOC and HAP from the waste gas stream are not included because those are already accounted form Points 002 and 003..
VOC emissions from this point are entirely for the pilot/purge gas stream, and have a 98% control efficiency built-in to the emission factor listed above. HAP emissions frommmbustion of the pilot/purge gas are all below 250lb/yr at the
requested flaw rate of 0.42 MMscf/yr..,
The waste gas flow rate used to calculate emissions is estimated based on the GLYCalc simulation for the TEG Dehydrators (poht 002 and 003). The waste gas heat. content (net heating value, LHV) for bothstill vent and flash tank streams
were calculatednbased on the stream compositions modeled by GLYCaIc. pplicant calculated waste gas heat content based on thewaste stream compositions estimated by GlyCalc. This is appropriate since the TCEQtechnical document
on which the NOx and CO'factors are based indicates that emissions are based on. the Net Heating Value.
The operators requesting a 98% control efficiency for this combustor that is used to control the still vent and flash tankfor 002 & 003. Since this control value is greater than the standard 91%control granted by the division, initial testing
will be required to demonstrate the combustors) capable of achieving a 98% destruction efficiency when controlling still nea and flash tank emissions from the dehydration m it. This testing requirement will inllude testing for NOx and -
CO. -. ... -.:
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point#
001
Process# _ SCC Code
01 3-10-001-60 Flares
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 11.23 0 lb/MMSCF
PM2.5 11.23, 0 lb/MMSCF
SOx 0.89 0 Ib/MMSCF
NOx 207,92 0 Ib/MMSCF
CO 415.09 0 lb/MMSCF
VOC 4.37 0 Ib/MMSCF
3 of 9 K:\PA\2019\19WE0171.CP1
Glycol Dehydrator Emissions Inventory
002 Dehydrator
(Facility AIRS ID:
2s i(kz '/102&1t a. '"i002.+a4,'
County
Plant Point
Section 02 - Equipment Description Details
Dehydrator Information
Dehyd rater Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Reboller Bumer
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMscf/day
gallons/minute
, flash tank,
and reboiler burner
One (Dl Methylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 60 MNEcf per day. This emissions
unit is equipped with 2 (Make: TBD, Model: TBD) electric driven glycol pump with a design capacity of 10 gallons per minute. This dehydration unit is equipped with a still
vent, flash tank, and reboiler burner.
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed dlrectlyta the Enclosed
Flare.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Dehydrator Still Vent and Flash Tank (it present)
(Requested Permit Limit Throughput=
Potential to Emit (PTE)Throughput= 21,900 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
NOTE: Combustion are accounted for with Point 001. Combustion and strearn info below is for informational purposes only.
MMscf per year Requested Monthly Throughput= 1860 MMscf per month
Still Vent Control
Condenser:
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation: -
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
1190
Total Gas to Combustor:
Avg. LW of waste gas:
Section 04- Emissions Factors 8, Methodologies
Dehydrator
Input'.Parameters
Inlet Gas Pressure
. Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylheraene
xyienes
n -Hexane
224-TMP
:tad Condenser Outlet Temperature: fa - ' '_"v"t`hA`12a1`"= DegreesF
98/ Control Efficiency 56
hr/yr
1869f Btu/scf
288 soS
1511.09
prig
deg F
Dry Gas Throughput:
Still Vent Primary Control: 21,900.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 2.5 MMscf/yr
Still Vent Secondary Contral: 0.o MMscf/yr
calculated by applicant, conservative compared to my calculation (which was 1842.7)
Control EfRciency %
Dry Gas Throughput:
Flash Tank Primary Control: 21,900.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 7.9 MMscfi/yr
calculated by applicant, conservative compared to my calculation (which was 1384.6) 0.0 MMscf/yr
Control Scenario
Primary
Secondary
Uncontrolled (lb/hr)
'10,2554
8.3407
9.5337
2.2603
Controlled (lb/hr)
0.4957
controlled (ib/hr)
0.0002`v;' d"V8,
0.0004
4.3656
0.6990
0.0111
0.0001:.
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled lib/hr)
VOC
29.9751. '
0.5997
Benzene
0.2293
0.0040
Toluene
0.1731
0.0035
Ethylbenzene
0.0244
0.0005
Xylenes
0.0338
0.0007
n -Hexane
0.4880
0.0098
224-TMP
0.0003
0.0001
1,860.0
0.2
Glycol Dehydrator Emissions Inventory
Emission Factors
Glycol Dehydrator
Emission Factor Source
Pollutant
Uncontrolled Controlled
(Ib/MMscf) (Ib/MMscf)
Throoghput)
(Dry Gas Throughput)
VOC
28.09
0.43816
'' rP` exsaOfM
Benzene
3.4282
0.04732
Toluene
3.88272
0.03348
Ethylbenzene
0.91708
0.00396
Xylene
1.75976
0.00612
n-eleeane
0.4748
0.00036
224TMP
0.00028
0.00008—
Section 05 - Emissions Inventory
Did operator request a buffer?
Requested Buffer ("A):
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
.PM10
PM2.5
500
NOx
CO
VOC
See Point 001
See Point 001
See Point 001
See Point 001
307.6
307.6 I 4.8
c 307.61 I 4.80
815
Hazardous Alr Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (Ibs/year)
Requested. Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n.Hexane
224 TMP
75078
75078
1036
75078
1036
85032
05032
733
85032
733
20084
20084
87
20084
87
38539
38539
134
38539
134
10398
10398
183
10398
183
6
6
2
6
2
Section 06- Regulatory Summary Analysis
Regulation 3, PartsA, 8
Regulation 7, Section XVII.B,D
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MACTSubpart HH (Area)
Regulation e, Part E, MACT Subpart HH (Major)
Regulation 8, Part f, MACT Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Dehydrator is subject to Regulation 7, Section XVII, B, D.3
The control device for this dehydrator Is not subject to Regulation 7, Section XVil.B.2.e
Dehydrator is subject to Regulation 7, Section XI I.H
The dehy unit meets the benzene exemption
You have indicated that this facility is not subject to Major Source requirements of MACT HH.
You have Indicated that this facility is not sublect to MACT HHH.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a
year of application submittal?
If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company request a control deuce efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and inklal compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
lithe company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve It?
It yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
No
Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F?
If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer.
Secondary em ns from combustion of the dehydrator waste gas not accounted fon oroalcuiat th this point since applicant Is permitting enclosed combustor separate ns pointl
o eas sso
value was calculated from the post condenser stream and uncontrolled flash tank stream composition ioolyCalc Vapor flow rates are from the same GlyCelc streams: The data in rows 55 and 56 reflect
Point 001(the enclosed combustor).
N"et heating
sedin analysis for
Source qualifies for ''benzeneeexemption" for MACT HH applicability based on the resulting controlled emission rates with required 98% destruction of VOC and further reductionsacheved w_h maximum condenser temperature
Ifsource fails stack test used to demonstrate compliance with 98% destruction, and a lower efficiency is requested, it is likely that the source will no longer qualify for the exemption for MACT HH. At this time, permit null include
requirements for nits qualifying frthe. benzene exemption based on requested limts in this permit
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point #
002
Process # 5CC Code
01
Uncontrolled
Pollutant
PM10
PM2.5
50x
NOx
VOC
CO
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Emissions Factor Control %
accounted for in Point 001
28.1
3.428
3.883
0.917
1.760
0.475
0.0003
Units
b/MMscf
b/MMscf
b/MMscf
b/MMscf
98.4 b/MMscf
b/MMscf
98.6 b/MMscf
99.1 b/MMscf
99.6 b/MMscf
99.7 b/MMscf
98.2 b/MMscf
71.4 b/MMscf
Glycol Dehydrator Emissions Inventory
003 Dehydrator
'Facility AIRS ID:
ARAB a,o W3... Ntan^r'
County Plant P int
Section 02- Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Reboiler Burner
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMscf/day
gallons/minute
, flash tank,
and reboiler burner
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 60 MMscf per day. This emissions
unit is equipped with 2 (Make: TBD, Model: TBD) electric driven glycol pump with a design capacity of 10 gallons per minute. This dehydration unit Is equipped with a still
• ant, flash tank, and reboiler humor.
•
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed directly no the Enclosed
Flare.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Dehydrator Still Vent and Flash Tank (If present)
Requested Permit Limit Throughput .'s*i a,+`o-y,900T MMscf per year Requested Monthly Throughput= 1860 MMscf per month
Potential to Emit (POE) Throughput = 21,900 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
NOTE: Combusti emissions are accounted for with Point 001. Combustion and stream: info below is for informational purposes only.
Still Vent Control
Condenser.
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flashtank Control
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
1190
Total Gas to Combustor:
Avg. LHV of waste gas:
Section 04 - Emissions Factors & Methodologies
Dehydrator
8760
hr/yr
hr/Yr
Btu/scf
902: scfh
1511.09
Degrees F
Dry Gas Throughput:
Still Vent Primary Control: 21,900.0 MMscf/yr
Still Vent Secondary Control: - 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 2.5 MMsd/yr
Still Vent5econdary Control: 0.0 MMscf/yr
calculated by applicant, conservativecompared to my calculation (which was 1842.7)
Control Efficiency St
Flash Tank Primary Control: 7.9 MMscf/Yr
calculated by applicant, conservative compared to my calculation (which was 1384.6) 0.0 MMscf/yr
Dry Gas Throughput:
Flash Tank Primary Control: 21,900.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Waste Gas Com busted:
The source used GRl-GLVCaIc 4.0 to estimate emissions. Wet gas composition wasmodeled using afacility-
a ed to he sirmlar to :he average of five j5) gas samples representative of.incoming g streams..
Input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
224-TMP
loos :-. psig
80 deg F
l0 Tai gam
Uncontrolled (lb/hr)
Control Scenario
Primary
Controlled (lb/hr)
Secondary
Controlled (lb/hr)
40.2554
0.4957
0.1137
0.0902
0.0094
07
9.5337
2.2683
4.3656
0.6990
0.0146
0;0111
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled lib/hr)
VOC
29.9751
0.5997
Benzene
0.2298.
0.0046
Toluene
0.1731
0.0035
Ethylbenzene
0.0244
0.0005
Xylenes
0.033E
0.0007
n -Hexane
0.4000
0.0090
224.TMP
0.0003 ..
0.0001
el, with a plant inlet gas
1,860.0
0.2
Glycol Dehydrator Emissions Inventory
Emission Factors
Glycol Dehydrator
Emission Factor Source
Pollutant
Uncontrolled Controlled
(Ib/MMsof) (Ib/MMscf)
Throughput)
(Dry Gas Throughput)
VOC
28.09
0.43816
w:
Benzene
3.4282
0,04732
Toluene
3.88272
0.03348
Ethylbenzene
0.91708
0.00396
Xylene
1.75976
0.00612
n4fexane
0.4748
0.00836
224 IMP
0.00028
0.00008
Section 05- Emissions Inventory
Did operator request a buffer?
Requested Buffer (%):
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
SOx
Nog
CO
VOC
See Point 001
See Point 001
See Point 001
See Point 001
307.6
307.6 I 4.8
307.61 1 4.80
815
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
75078
75078
1036
75078
1036
85032
85032
733
85032
733
20084
20084
87
20084
87
38539
38539
134
38539
134
10398
10398
183
10398
183
6
6
2
6
2
Section 06- Regulmery Summary Analysts
Regulation 3, PartsA, B
Regulation 7, Section XVII.B,D
Regulation 7, Section 11/11.0.2.0
Regulation 7, Section 011.9
Regulation e, Part E, MACE Subpart HH (Area)
Regulation 8, Part E, MAR Subpart HH )Major)
Regulation 8, Part E, MAR Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a pennh
Dehydrator is subjectto Regulation 7, Section XVII, 0,0_3
The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e
Dehydrator is subject to Regulation 7, section XII.H
The dohy unit meets the benzene exemption
You have indicated that this facility is not subject to Major Source requirements of MAUI HH.
You have indicated that this facility is not subject to MAR HHH.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a
year of application submittal?
If no, the permit will contain en "Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company request a control device efficiency greater than 95% fore flare or combustion device?
if yes, the permit will contain end initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling
If thecompany has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it?
If yes, the penult will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
No
Is the company usiig a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F7
dyes, the permit will contain en "Initial Compliance" testing requirement AND a permit ceedition,speclfying the minimum combustion chamber temperature for the thermal oxidizer.
_Section 08 Technical AnalysisNotes
Secondary emissions from combustion of the dehydrator waste ga not accounted for or calculated with this point since appicant is permitting the enclosed combustor as a separate emsons pont(pont 001). Net heating
value was calculated from the postcondenser stream and uncontrolled flash tank stream compositionin GlyCalc. Vapor -flow rates are from the same GlyCalc streams. The data in rows 55 and 56 reflect values used I n analysis for
Pont 001 (the eclosed combustor).
Source qualifies for benzene exemption" for MACT HH applicability based on theresuling controlled emsson rates with required 98% destruction of VOC and further reductions achieved wish maximum condenser temperature
If source fails stack test used to demonstrate compliance 0th 98% destruction, and a lower efficency H requested, it is likely that the source All no longer qualify for this exemption for MACi HH. At this time, permit will include
requirements tar units qualifying for the benzene exemption based on requested limits in this permit.
Section 09 - Inventory 5CC Coding and Emissions Factors
AIRS Point #
003
Process # SCC Code
01
Pollutant
PM10
PM2.5
SOx
NOx
VOC
CO
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Uncontrolled
Emissions Factor Control % Units
b/MMscf
b/MMscf
b/MMscf
b/MMscf
28.092 98.440 b/MMscf
accounted for ln Point 001 b/MMscf
3.428 98.620 b/MMscf
3.883 99.138 b/MMscf
0.917 99.568 b/MMscf
1.760 99.652 b/MMscf
0.475 98.239 b/MMscf
-0.0003 71.429 b/MMscf
accounted for in Point001
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name
County AIRS ID
Plant AIRS ID
Facility Name
Rocky Mountain Midstream, LLC
123
AO2B
Auburn Compressor Station
History File Edit Date
4/8/2019
Ozone Status
Non -Attainment
EMISSIONS - Uncontrolled (tons ner year
EMISSIONS With Controls (tons per year
POIN
T
AIRS
PERMIT
Description
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
REMARKS
Previous FACILITY TOTAL
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
New Facility - No Previous Total
Previous Permitted Facility total
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
001
19WE0171
Combustor for dehy waste
0.1
0.1
0.0
2.2
0.1
4.4
0.0
0.1
0.1
0.0
2.2
0.1
4.4
0.0
Representative sample, need SSEF dev
002
19WE0171
TEG Dehy "Dl"
307.6
114.6
4.8
1.1
Representative sample, need SSEF dev
003
19WE0171
TEG Dehy "D2"
307.6
114.6
4.8
1.1
Representative sample, need SSEF dev
004
GP02
Cat G3608 **See Note 1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE — SEE NOTE 1
005
GP02
Cat G3608 **See Note 1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE — SEE NOTE 1
006
GP02
Cat G3608 **See Note 1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE — SEE NOTE 1
APEN-Exempt / Insignificants
0.0
0.0
TEG Reboilers (2)
0.1
0.1
0.0
1.3
0.1
1.1
0.0
0.1
0.1
0.0
1.3
0.1
1.1
0.0
From Feb 2019 application
Slop Tanks (2 x 100 -bbl)
0.0
0.0
0.0
0.0
From Feb 2019 application
Loadout of slop
0.1
0.0
0.1
0.0
From Feb 2019 application
Fugitive leaks
0.4
0.0
0.4
0.0
From Feb 2019 application
MSS Pigging
0.0
0.0
0.0
0.0
From Feb 2019 application
MSS Blowdowns
1.0
0.0
1.0
0.0
From Feb 2019 application
Compressor Blowdowns (combined)
2.7
0.1
2.7
0.1
From Feb 2019 application; combined
across all three separate engines here
Compressor Venting
0.5
0.0
0.5
0.0
From Feb 2019 application
FACILITY TOTAL
2.4
2.4
0.0
0.0
39.7
720.3
0.4
224.2
250.1
2.4
2.4
0.0
0.0
39.7
47.8
0.4
14.2
7.6
VOC: Syn Minor (NANSR and OP)
NOx: Minor (NANSR and OP)
CO: Syn Minor (PSD and OP)
HAPS: Syn Minor HCHO, B, T, Eb, X, n -
hex,& Total
HH: Syn Minor + affected Area
Permitted Facility Total
2.3
2.3
0.0
0.0
38.4
716.0
0.0
223.1
249.8
2.3
2.3
0.0
0.0
38.4
43.51
0.0
13.1
7.3
Excludes units exempt from
(A) Change in Permitted Emissions
2.3
2.3
0.0
0.0
38.4
43.5
0.0
13.1
Pubcom required. Modeling not required
based on current application, but may be
required depending on GP02 applications
(see Note 1 below)
Note 1
Total VOC Faci
Al Change in Total Permitted VOC
ity Emissions (point and fugitive
emissions (point and fugitive
48.2
Facility is eligible for GP02 because < 90
Project emissions less than 25/50 tpy
43.5
rep zu ra apps
numbers are not
NOx emissions
should be revoked.
non urny rncruaea Hrtrvs Tor punts uu i-uua, out me Lumpressur engines at puuds u4, u , uuo are t.enamry pan uT oils pruleLl . Hppr c.ertt ura nut yet suumit Hrtrvs Tor puuub uu4, uuo, vun turuz) Decause serial
yet available. Applicant did furnish engine spec sheets upon which I calculated the emissions entered above. The engineer that reviews new GP02s for points 004, 005, 006 must make certain that total controlled
do not exceed 40 tpy for all of the listed activities including points 001 + 002 + 003 + 004 + 005 + 006; if 40 tpy NOx is exceeded then the facility is not eligible for GP02 and also modeling is required, and 19WE0171
Note 2
Page 8 of 9
Printed 4/9/2019
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY - HAPs
Company Name Rocky Mountain Midstream, LLC
County AIRS ID 123
Plant AIRS ID A02B
Facility Name Auburn Compressor Station
POIN1 PERMIT Description
I
Formaldehyde
AdeteuelrydW
Acrolein
Benzene
Toluene
Ethylbonzene
Xylenes
n -Hexane
MCOH
.4'.H2S
TOTAL
lips)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
19WE0171
Combustor for dehy waste streams
all HAPs de minimis for this point
0.0
002
19WE0171
TEG Dehy"D1"
75078
85032
20084
38539
10398
6
114.6
003
19WE0171
TEG Dehy"D2"
75078
85032
20084
38539
10398
6
114.6
004
GP02
Cat 03608 "See Note 1 below**
11105
1224
753
64
60
6
27
163
366
37
6.9
005
GP02
Cat G3608 "See Note 1 below**
11105
1224
753
64
60
6
27
163
366
37
6.9
006
GP02
Cat G3608 *'See Note 1 below**
11105
1224
753
64
60
6
27
163
366
37
6.9
APEN-Exempt / Insignificants
TEG Reboilers (2)
2
46
0.0
Slop Tanks (2 x 100 -bbl)
8
0.0
Loadout of slop
1
12
0.0
Fugitive leaks
1
1
1
13
0.0
MSS Pigging
0.0
MSS Blowdowns
5
9
2
5
75
0.0
Compressor Blowdowns (combined)
15
24
6
15
210
0.1
Compressor Venting
2
4
1
2
35
0.0
TOTAL (tpy)
16.7
1.8
1.1
75.2
85.1
20.1
38.6
10.8
0.5
0.1
0.0
0.0
250.1
*Total Reportable = all HAPs where uncontrolled emissions > de minimus values
Red Text: uncontrolled emissions < de minimus
Emissions with controls (Ibs per year
POIN1 PERMIT Description
I
Formaldehyde
...aldehyde
Acrolein
Benzene
Toluene
Ethylbenzeno
Xylenes
n -Hexane
McOH
MT.'
H2S
TOTAL
Imr1
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
19WE0171
Combustor for dehy waste streams
all HAPs de minimis for this point
0.0
002
19WE0171
TEG Dehy "D1"
1036
733
87
134
183
2
1.1
003
19WE0171
TEG Dehy "D2"
1036
733
87
134
183
2
1.1
004
GP02
Cat 03608 "See Note 1 below**
724
1224
753
64
60
6
27
163
366
37
1.7
005
GP02
Cat 03608 **See Note 1 below**
724
1224
753
64
60
6
27
163
366
37
1.7
006
GP02
Cat 03608 "See Note 1 below**
724
1224
753
64
60
6
27
163
366
37
1.7
APEN-Exempt / Insignificants
TEG Reboilers (2)
2
46
0.0
Slop Tanks (2 x 100 -bbl)
8
0.0
Loadout of slop
1
12
0.0
Fugitive leaks
1
1
1
13
0.0
MSS Pigging
0.0
MSS Blowdowns
5
9
2
5
75
0.0
Compressor Blowdowns (combined)
15
24
6
15
210
0.1
Compressor Venting
2
4
1
2
35
0.0
TOTAL (tpy)
1.1
1.8
1.1
1.1
0.8
0.1
0.2
0.6
0.5
0.1
0.0
0.0
7.6
9
19WE0171.CP1
4/9/2019
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer: Andy Gruel
Package #: 393474'.
Received Date: 2/15/2019
Review Start Date: 3/14/2019
Section 01- Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical
Address/Location:
County:
Type of Facility: .Natural Gas Compressor Station
What industry segment? Oil & Natural Gas Production & Processing
Is this facility located in a NAAQS non -attainment area? '.. Yes
If yes, for what pollutant? ❑ Carbon Monoxide (CO) ❑ Particulate Matter (PM) ❑✓
Rocky Mountain Midstream, LLC
123
A02B
Auburn Compres
Section 26, Township 5N, Range 65W
Weld County
Section 02 - Emissions Units In Permit Application
Quadrant
Section
Township
Range
26
5N
Ozone (NOx & VOC)
AIRS Point #
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Process Flare
Cl
Yes
19WE0171
CP1
Permit Initial
tssuan .
Controls dehys
002
Dehydrator;'
D1
003
-1 Dehydrator . ,
D2
004
,:'<Natural Gas RICE . . -'
- TBD -- GP02 Application to be submitted after 19WE0170 issuance'
005
Natural Gas RICE=,.-.
TBD:-- GP02 Application to be submitted after 19WE0170 issuance
006
Natural Gas RICE
TBD — GP02 Application to be submitted after 19WE0170 issuance
Section 03 - Description of Project
New compressor station in the ozone non -attainment area of Weld County. APEN-exempt equipment associated with this project are rebalers for the TEG dehydrators, two
1000 -bbl slop tanks, truck loadout of slop, fugitive equipment leaks, planned maintenance/startup/shutdown activities, compressor venting, pigging, and blowdowns.
The project includes threeCaterpillar G3608 compression engines, but the applicant has not yet submitted the GP02 requests for those because the serial number is not
available. The NOx emissions from those three engines put the facility permitted emissions very close to the threshold to require ambient air monitoring for N0x (40 tpy),
and the applicant has been notified that if those GP02 applications push the site over 40 tpy NOx then the permit for 19WE0170 may be revoked until modeling analysis can
be completed.
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why? Requesting Synthetic Minor Permit
Section 05 -Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? No
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Yes
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
'.. No, based on construction permit application. Forthcoming GP02 applications may cause the project to re
modeling analysis.
No
Yes
502 N0x CO VOC PM2.5 PM10 TSP HAPs
Is this stationary source a major source?
If yes, explain what programs and which pollutants heft SO2
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
No
NOx CO
C
✓
VOC
❑ ❑
PM2.5 PM10 TSP HAPs
❑ ❑
Combustor Emissions Inventory
Section 05 - Emissions Inventory
001 Combustor
Facility AIRS ID;.
County
AOZB
Pion
001
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit Description:
Emission Control Device Description:
Requested Overall VOC & HAP Control Efficiency %:
onirol waste gas streams fron
EC4II 25 L 33-0035 00y, sec Toll
ofnt 002 and Point 00
This is the control efficiency for VOC and HAP at points 002 and 003. Emissions from this point
001 only include secondary emissions from that combustion.
Limited Process Parameter Waste gas + purge gas + pilot gas
Gas meter No, gas flow is calculated based on monthly GLYCalc report for points 002 and 003 and based on actual gas throughput
Section 03- Processing Rate Information far Emissions Estimates
Secondary Emissions - Combustion of dehydrator waste gas
Pilot burners (2 @ 22 scfh each)
Purge fuel f?I,d_
Plot + Purge
Waste Gas (total 2 dehys,flash+still)
Total (pilot + purge + waste)
Waste Gas LHV
Fuel (pilot and purge) LHV
Pilot and purge VOC
Pilot and purge MW
Actual Throughput =
cfh
cfh
cfh
0.42 MMscf/yr
2380•scfh from Point 002 and Point 003; from GLYCalc output
20.85 MMscf/yr
0.04 MMscf/month
1.77 MMscf/month
2428 scfh
p`fi5;12` btu/scf
Btu/scf
Ib/Ibmol
MMscf/yr
21.269 MMscf/yr
from Point 002 and Point 003; from GLYCalc output
based on GLYCalc dry gas stream
based on GLYCalc dry gas stream
based on GLYCalc dry gas stream
3.67 MM6tu/yr
Requested Permit Limit Throughput =^ gs''."-"'B1"P^"27t MMscf/yr
Potential to Emit (PTE) Throughput =
Requested Monthly Throughput = 1.81 MMscf per month
Section 04 - Emissions Factors & Methodologies
Description
J=missions attributed to this equii
gas rsecessay,for proper nueration of
gsoicated wixh the combustion of purg
Pollutant
21.27 MMscf/yr
nc io hides rorob emissions of NOx, €C, PM, SO2 associated wit. so
or. Emissions a₹ VOC associated with uncembusted VOC in ti
list as.
Primary Control Device
Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
Uncontrolled
lb/MMscf
(Gas Throughput)
rus�mn or w„
dehvlirator 5
e pas b am TEG dehy'#mtoS
asns are ecoun.ed ,orw
Emission Factor Source
PM10
PM2.5
0.0075
11.259
11.259
0.889
075 ix
SOx
NOx
CO
VOC
0.0006
61
0.275
208.530
416.304
Process 02:"Combustion of;pilot
d per)
Pollutant
PM10
PM2.5
SOx
NOx
Co
Primary Control Device
Uncontrolled Uncontrolled
(lb/MMBtu) #REF!
(Waste Heat
Combusted)
0.0075
0.0075
0.1380 7iJf"iy,
0.2758
(Gas Throughput)
9.597
0.758
177.744
354.844
221.107
Emission Factor Source
Po 02 and 003.. Emrss,ons of V
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested MonthlyLimits
Controlled
(Ibs/month)
PM10
PM2.5
SOx
NOx
CO
VOC
0.12
0.12
0.12
20
0.12
0.12
0.12
20
0.01
0.01
0.01
2
2.21
2.21
2.21.
376
4.41
4.41
4.41
750
0.05
0.05
0.05
8
,vitb Point 002 and Point 003 astive(lpi)
glare
d purge
iy those
2 of 9
K:\PA\2019\19 W E0171.CP1
Combustor Emissions Inventory
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
(See regulatory applicability worksheet for detailed analysis)
I Source requires a permit
Section 07 - Initial and Periodic Sampling and Testing Requirements
#REF(
Using Gas Throughput to Monitor Compliance
Does the company use site specific emission factors based on a gas sample to estimate emissions?
This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if
the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permifwill contain an.' Initial Testing Requirement to collect a site -specific gos sample from the equipment being permitted and conduct an emission factor
'analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Will the operator have a meter installed and operational upon startup of this point? No - N/A
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based
on inlet and outlet concentration sampling
Section 08 -Technical Analysis Notes
VOC and({AP from the waste gas stream are not included because thoseare'already accounted for in Points 002 and
VOC emissions,from thispoint are entirefyforthe pilot%purge gas stream, and have a 98% control efficiency built-in to the emissswn factor listed above
requested flow rate of 0.42 MMscf/yr:;-
om combgsstion ofthe pilot/purgegas are all below.250 Ib/yr'at
r The waste`gas flow rate,used to calculate eeelssions ieest)mated based on the GLYCalcsim ulatiun for the TfiG Dehydrators5(pont•002 and:0031,. The waste gas bee cunteet (net `heating value, Edit) for both still Vent and flash tank streams ra
ll were caicalateclbased onthe streamv;csppositions,o'eled6 GLYCap�Ic hganfcalculated,waste gas heatcontent bonedonfhewaste stream composrtronsestimatedy Gly bCalc.Thinis'apprgprnatesiose'Che;TCEQtechvical documept_a-
m„p y
on whichthe NOx and Cofactors are based indicates that emissions are based on: the Net Heating Value .n "t=_ ".t"
he operator isrequesniog a 98%cnmrgl efficency f¢r this -combustor that as used -rol the sttl6vent and flash tankfor D02&OOB, Sinie this comrolvalue is greaterthilistbe stndard 951.cpntrol grantedby the Division, iuit3al testing
sill be required to demonstrate he combusnurls capable of achieving a 98%destruction efficiency when controlhngstiil vent and flash tank emisslops•from the dehydration wat, Thistestmg regoirement will -inilode Wolin rfor NOR' and n ..
Section 09 - Inventory 5CC Coding and Emissions Factors
AIRS Point #
Process # SCC Code
001 01 3-10-001-60 Flares
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 11.23 0 lb/MMSCF
PM2.5 11.23 0 Ib/MMSCF
SOx 0.89 0 Ib/MMSCF
NOx 207.92 0 lb/MMSCF
CO 415.09 0 Ib/MMSCF
VOC 4.37 0 lb/MMSCF
3 of9
K:\PA\2019\19 W E0171. CP1
Glycol Dehydrator Emissions Inventory
002 Dehydrator
IFacility Allis ID:
Section 02 - Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Rehoiler Bumer
Stripping Gas
Dehydrator Equiprent Description
Emission Control Device Description:
123
County
A026 - 002
Plant Point
MMscf/day
gallons/minute
flash tank,
and reboiler burner
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design opacity of 60 MMscf per day. This emissions
unit is equipped with 2 (Make: TBD, Modei:TOD) electric driven glycol pump with a design capacity of 10 gallons per minute. This dehydration unit is equipped with a still
vent, flash tank, and reboiler burner.
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed directly to the Enclosed
Flare.
Section 03- Processing Rate Information for Emissions Estimates
Primary Emissions- Dehydater Still Vent and Flash Tank (If present)
Requested Permit Limit Throughput =
Potential to Emit (PTE) Throughput = 21,900 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
NOTE: Combustion emissions are accounted for with Point 001. Combustion and stream info below is for informational purposes only.
MMscf per year
Requested Monthly Throughput= 1860 MMscf per month
Still Vent Control
Condenser:
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Healing Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation:
Secondary control. device:
Secondary control device operation:
Flesh Tank Gas Heating Value
Flask Tank Waste Gas Vent Rate:
1190
Total Gas to Combustor:
Avg. LHV of waste gas:
Section 04- Emissions Factors 0, Methodologies
Dehydrator
input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
1}'Cale v.0 to estfine
to the average of fii
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
224-TMP
1098
80
0
Requested Condenser Outlet Temperature: 125. Degrees F
98%Control Efficiency%
760 hr/yr Request¢tl TO Temp Degrees F
Control E000iency%
hr/yr
1859: Btu/scf
288 scth
hr/Yr
1400 Btu/scf
902 scfh
1511.09
prig
deg F
gpm
Dry Gas Throughput:
Still Vent Primary Control: 21,900.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 2.5 MMscf/yr
Still Ventsecondary Control: 0.0 MMscf/yr
calculated by applicant, conservative compared to my calculation (which was 1842.7)
Control Efficiency%
Flash Tank Primary Control: 7.9 MMscf/yr
calculated by applicant, conservative compared to my calculation (which was 1384.6) 0.0 MMscf/yr
Dry Gasmneughput:
Flash Tank Primary Control: 21,900.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Control Scenario
Primary
Secondary
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled (lb/hr)
7`48.2554.
0.4957 ):
0.1137.
0.0802
0.0094
0.0146
0.0111
0.0001
8.3407
9.5337
2.2683
4.3655
0.6990
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled (lb/hr)
VOC
29.9751
0.5997
Benzene
:02298
0.0046
Toluene
: 0.1731
0.0035
Ethylbenzene
0.0244
0.0005
Xylenes
0.0338
0.0007
n -Hexane
0.4880
0.0098.
224-TMP
-.'0.0003
0.0301
th a plant inlet gas
1,860.0
0.2
Glycol Dehydrator Emissions Inventory
Emotion Factors
Glycol Dehydrator
Emission Factor Source
Pollutant
Uncontrolled Controlled
(Ib/MMscf) (Ib/MMscf)
Throughput)
(Dry Gas Throughput)
VOC
28.09
0.43816
�}a
ti ti
� I
5
Benzene
3.4282
0.04732
Toluene
3.88272
0.03348
Ethylbenzene
0.91708
0.00396
Xylene
1.75976
0.00612
n Hexane
0.4748
0.00836
224 IMP
0.00028
0.00008
Section 05 - Emissions Inventory
Did operator request a buffer?
Requested Buffer (%):
Critetia Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled _ Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
fibs/month)
PM10
PM2.5
S0x
NOx
CO
VOC
See Point 001
See Point 001
See Point 001
See Point 001
307.6
307.6 I 4.8
307.61 I 4.80
815
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
fibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
75078
75078
1036
75078
1036
85032
85032
733
85032_
733
20084
20084
87
20084_
87
38539
38539
134
38539
134
10398
10398
183
10398
183
6
6
2
6
2
Section 06 - Regulatory Summary Analysis
Regulation 3, PartsA, B
Regulation 7, Section XVII.B,D
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, PertE, MAR Subpart HH (Area)
Regulation 8, Part E, MAR Subpart HH (Major)
Regulation 8, Part E, MACT Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Dehydrator is subjectto Regulation 7, Section XVII, 8, 0.3
The control device for this dehydrator Is not subject to Regulation 7, Section XV0.5.2.e
Dehydrator A subject to Regulation 7, Section 011.8
The dehy unit meets the benzene exemption
you have indicated that this facility is not subject to Melon Source requirements of MAR HH.
you have indicated that this facility is not subject to MAST HHH.
Section 07- Initial and Periodic Sampling and Testing Requirements •
Was the extendedwetgas sample used in the GlyCalc model/Process model site -specific and collected within a
year of application submittal? Wiz.
If no, the permit will contain en 'Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company request a control device efficiency greater than 95% fore flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it?
If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
No
Is the company using a thermal oxidizer AND requesting minimum combustion chamber temperature lower than 1,400 degrees F?
If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer.
Section 08 Technical Analysis Notes , ,
Secondary emissions from combustion of the dehydrator waste gas are not accounted for or calculated with this point since applicants permitting the enclosed combustor as a separate emssons point(point001). Net heating
value was calculated from the post condenser stream and uncontrolled flash tank stream composition in GlyCalc. Vapor flow rates are from Me same Glrculc streams.The data fn rows 55 and SE reflect values used In analysis for
Point DOl (the enclosed combustor).
Source qualifies for benzene exemption' for MACfHH applicability based on the resultingcontrolled emission rates with required 91% destruction of VOC and further reductions achieved yeah max mum condensertemperat.ire
If source fails stack test used to demonstrate compliance with 98% destruction, and a lower efficiency isrequested, it is likely that the source will no longer qualify for the exempton for MAc HH. At ttime, pecrnn will include
requirements for units qualifying for the benzeneexemption based on requested limo in this permit.
Section 09- Inventory SCC Coding and Emissions Factors
AIRS Point
CO2
Process #
01
SCC Code
Uncontrolled
Pollutant Emissions Factor Control %
PM10
PM2.5
SOx
905
VOC 28.1
CO
Benzene 3.428
Toluene 3.883
Ethylbenzene 0.917
Xylene 1.760
n -Hexane 0.475
224 TMP 0.0003
accounted for in Point001
Units
b/MMscf
b/MMscf
b/MMscf
b/MMscf
98.4 b/MMscf
b/MMscf
98.6 b/MMscf
99.1 b/MMscf
99.6 b/MMscf
99.7 b/MMscf
98.2 b/MMscf
71.4 b/MMscf
Glycol Dehydrator Emissions Inventory
003 Dehydrator
(Facility Allis ID:
County
A02B
Plant Point
Section 02 -Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Reboiler Burner
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMscf/day
flash tank,
and reboiler burner
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number. TBD) with a design capacity of 60 MMscf per day. This emissions
unit is equipped with 2 (Make: TBD, Model: TOD) electric driven glycol pump with a design capacity of 10 gallons per minute. This dehydration unit is equipped with a still
vent, flash tank, and reboiler burner.
Emissions from the still vont am routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed directly to the Enclosed
Flare.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Dehydrator Still Vent and Flash Tank (if present)
(Requested Permit Limit Throughput=
Potential to Emit (PTE) Throughput = 21,900 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
NOTE: Combustion issions aa accounted for with Point 001. Combustion and stream info below is for informational purposes only.
21,900 :..... MMscf per year Requested Monthly Throughput= 1060 MMscf per month
Still Vent Control
Condenser.
Condenser emission reduction claimed:
Primary control device:
Primary control deice operation:
Secondary control device:
Secondary controidevice operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
Total Gas to Combustor.
Aug. LHV of waste gas:
1190
Section 04- Emissions Factors & Methodologies
Dehydrator
The source used 950 00YCalc 4.0 to estimate eml sons. Wetgas composttIon was modeled coin
assumed to be similar to the average of five (5) gas samples representative of incoming gas streams.
Input Parameters
Inlet Gas Pressure 1098 psig
inlet Gas Temperature 80 deg F
Requested Glycol Recirculate Rate 10 gpm
RequestedCondenser Outlet Temperature: ' : .!
..,...
Control Efficiency %
h/yr Requested TO Temp 4yi
Control Efficiency %
hr/yr
Btu/scf
hr/yr
1400 Btu/scf
902 sufh
1511.09
Dry Gas Throughput:
Still Vent Primary Control: 21,900.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 2.5 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
calculated by applicant, conservative compared to my calculation (which was 1842.7)
98% Control Efficiency %
Control Efficiency %
Dry Gas Throughput:
Flash Tank Primary Control: 21,900.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 7.9 MMscf/yr
calculated by applicant, conservative compared to my calculation (which was 1384.6) 0.0 MMscf/yr
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
224-TMP
Uncontrolled (Ib/hr)
ide ProMaa model, th plant miet gas
Control Scenario
Primary
Controlled Ilb/hr)
Secondary
controlled (lb/hr)
40.2554
8:3407
9.5337
2.2680
4.3656
0.6990
0.4957
0.1137
0.0802
0.0094
0.0111
0.0001 ..
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (Ih/hr)
Controlled (lb/hr)
Controlled (lb/hr)
VOC
29.9751
0.5997
Benzene
0.2298
0:0046
Toluene
0.1731
0.0035
Ethylhenzene
0.0244
0.0005
Xylenes
: 0.0338
0.0007
n -Hexane
0.4880
0.0098
224-TMP
„-,:. -.3..0.0003
-
0.0001
1,860.0
0.2
Glycol Dehydrator Emissions Inventory
Emission Factors
Glycol Dehydrator
Emission Factor Source
Pollutant
Uncontrolled Controlled
(lb/MMscf) (Ib/MMscf)
Throughput)
(Dry Gas Throughput)
VOC
28.09
0.43816�'
'8 )
`¢ _
Benzene
3.4282
0.04732
Toluene
3.88272
0.03348
Ethylbenzene
0.91708
0.00396
Xylene
1.75976
0.00612
n -Hexane
0.4748
0.00836
224TMP —
0.00028
0.00008
Section 05 - Emissions Inventory
Did operator requesta buffer?
Requested Buffer (%):
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
50x
NOx
Co
VOC
See Point 001
See Point 001
See Point 001
See Point 001
307.6
307.6 I 4.8
307.61 I 4.80
815
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
i
Benzene
Toluene
Ethylbenzene
Xylene
it -Hexane
224TMP
75078
75078
1036
75078
1036
85032
85032
733
85032
733
20084
20084
87
20084
87
38539
38539
134
38539
134
10398
10398
193
10398
183
6
6
2
6
2
Section 06 - Regulatory Summary Analysts
Regulation 3, PartsA, B
Regulation 7, Section )6/11.B4O
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MACT Subpart HH (Area)
Regulation 8, Part E, MACT Subpart HH (Major)
Regulation 8, Part E, MACTSuhpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Dehydrator is subject to Regulation 7, Section XVII, 8, D.3
The control device for this dehydrator is not subject to Regulation 7, Section XVI I.B.2.e
Dehydrator is subject to Regulation 7, Section X11.0
The dehy unit meets the benzene. exemption
You have indicated that this facility is not subject to Major Source requirements of MACT 66.
You have indicated that this facility is not subject to MACT HHH.
Section 07 - Initial and Periodic Sampling end Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site-speclflc and collected within a
year of application submittal? Et;}
If no, the permit will contain en "Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and Initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling.
If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to echieve4t?
If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
No
Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lowerthan 1,400 degrees F7
If yes, the permit will contain en "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer.
Secondary emissions fromcombusbon of the dehydrator waste gas are nt accounted for or calculated with this point since applicant is permittingg the enclosed combustor as a separate emssons pant (poet 001). N. et heatng
valve was calculated from the post condenser stream and uncontrolled rush tank stream composition in GlyCalc. Vapor flow rates are from the same GlyCalc streams The data in rows 55 ant d 55 reflect es used in analysis for
Pont 001 (the enclosed combustor)
Source qualifies 'benzene exemption" for MACT HH applicability based on the resulting controlled emission rates with required 98%destruction 0150C and further reductions achieved With maximum condenser temperature
If source fails stack test used to demonstrate compliance with 98% destruct on,: and a lower efficiency is requested, It is likely that the sourcewll no longer qualify for the exemption for MACT HH, At the time, permit wllinclude )
requirements for units qualfying for the benzene exemption based on requested limits in this permit
AIRS Point #
003
Process # SCC Code
01
Section 09 - Inventory SCC Coding and Emissions Factors
Uncontrolled
Pollutant Emissions Factor Control %
PM10
PM2.5
500
NOx
VOC
CO
Benzene 3.428
Toluene 3.883
Ethylbenzene 0.917
Xylene 1.760
n -Hexane 0.475
224 TMP 0.0003
accounted for in Point001
28.092 98.440
accounted for in Point 001
98.620
99.138
99.568
99.652
98.239
71.429
Units
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
h/MMscf
h/MMscf
b/MMscf
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name
County AIRS ID
Plant AIRS ID
Facility Name
Rocky Mountain Midstream, LLC
123
A02B
Auburn Compressor Station
History File Edit Date
4/8/2019
Ozone Status
Non -Attainment
EMISSIONS - Uncontrolled (tons per year
EMISSIONS With Controls (tons Der year
POIN
T
AIRS
PERMIT
Description
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
REMARKS
Previous FACILITY TOTAL
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
New Facility - No Previous Total
Previous Permitted Facility total
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
001
19WE0171
Combustor for dehy waste
0.1
0.1
0.0
2.2
0.1
4.4
0.0
0.1
0.1
0.0
2.2
0.1
4.4
0.0
Representative sample, need SSEF dev
002
19WE0171
TEG Dehy "D1"
307.6
114.6
4.8
1.1
Representative sample, need SSEF dev
003
19WE0171
TEG Dehy "D2"
307.6
114.6
4.8
1.1
Representative sample, need SSEF dev
004
GP02
Cat G3608 **See Note 1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE -SEE NOTE 1
005
GP02
Cat G3608 **See Note 1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE - SEE NOTE 1
006
GP02
Cat G3608 **See Notez1 below**
0.7
0.7
12.1
33.6
72.9
6.9
0.7
0.7
12.1
11.3
2.9
1.7
**** TENTATIVE --.SEE NOTE 1
APEN-Exempt / Insignificants
0.0
0.0
TEG Reboilers (2)
0.1
0.1
0.0
1.3
0.1
1.1
0.0
0.1
0.1
0.0
1.3
0.1
1.1
0.0
From Feb 2019 application
Slop Tanks (2 x 100 -bbl)
0.0
0.0
0.0
0.0
From Feb 2019 application
Loadout of slop
0.1
0.0
0.1
0.0
From Feb 2019 application
Fugitive leaks
0.4
0.0
0.4
0.0
From Feb 2019 application
MSS Pigging
0.0
0.0
0.0
0.0
From Feb 2019 application
MSS Blowdowns
1.0
0.0
1.0
0.0
From Feb 2019 application
Compressor Blowdowns (combined)
2.7
0.1
2.7
0.1
From Feb 2019 application; combined
across all three separate engines here
Compressor Venting
0.5
0.0
0.5
0.0
From Feb 2019 application
FACILITY TOTAL
2.4
2.4
0.0
0.0
39.7
720.3
0.4
224.2
250.1
2.4
2.4
0.0
0.0
39.7
47.8
0.4
14.2
7.6
VOC: Syn Minor (NANSR and OP)
NOx: Minor (NANSR and OP)
CO: Syn Minor (PSD and OP)
HAPS: Syn Minor HCHO, B, T, Eb, X, n -
hex,& Total
HH: Syn Minor + affected Area
Permitted Facility Total
2.3
2.3
0.0
0.0
38.4
716.0
0.0
223.1
249.8
2.3
2.3
0.0
0.0
38.4
43.5
0.0
13.1
7.3
Excludes units exempt from
(A) Change in Permitted Emissions
2.3
2.3
0.0
0.0
38.4
43.5
0.0
13.1
Pubcom required. Modeling not required
based on current application, but may be
required depending on GP02 applications
(see Note 1 below)
Note 1
Total VOC Faci
pQ To Pgfmltted VOC
ity Emissions (point and fugitive
emissions (point and fugitive
48.2
Facility is eligible for GP02 because < 90
Project emissions less than 25/50 tpy
43.5
reo to la approauon only inctuaea rtrcrvs Tor puns uu r-uua, out me compressor engines at pum(SU , b are eel (dully pelt ur vas pruleCt . HppnwflL aiu nut yet suouut r.rcrvs Lir puns uu4, uuo, uuo tt.ruz) oecause serial.'
numbers are not yet available. Applicant did furnish engine spec sheets upon which I calculated the emissions entered above. The engineer that reviews new GP02s for points 004, 005, 006 must make certain that total controlled
NOx emissions do not exceed 40 tpy for all of the listed activities including points 001 + 002 + 003 + 004 + 005 + 006; if 40 tpy NOx is exceeded then the facility is not eligible for GP02 and also modeling is required, and 19WE0171
should be revoked.
Note 2
Page 8 of 9
Printed 4/9/2019
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY - HAPs
Company Name Rocky Mountain Midstream, LLC
County AIRS ID 123
Plant AIRS ID AO2B
Facility Name Auburn Compressor Station
Emissions - uncontrolled (Ibs per year
POINT PERMIT
I
Description
...moo.
Acetaldehyde
Acrolein
Benzene
Toluene
Ethyllcu ne
Xylenes
n -Hexane
McOH
234 T.'
H2S
TOTAL
013Y)Previous
FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
19WE0171
Combustor for deny waste streams
all HAPs de minimis for this point
0.0
002
19WE0171
TEG Dehy"D1"
75078
85032
20084
38539
10398
6
114.6
003
19WE0171
TEG Dehy"D2"
75078
85032
20084
38539
10398
6
114.6
004
GP02
Cat G3608 "See Note 1 below**
11105
1224
753
64
60
6
27
163
366
37
6.9
005
GP02
Cat G3608 "See Note 1 below"
11105
1224
753
64
60
6
27
163
366
37
6.9
006
GP02
Cat 63608 "See Note 1 below**
11105
1224
753
64
60
6
27
163
366
37
6.9
APEN-Exempt / Insignificants
TEG Reboilers (2)
2
46
0.0
Slop Tanks (2 x 100 -bbl)
8
0.0
Loadout of slop
1
12
0.0
Fugitive leaks
1
1
1
13
0.0
MSS Pigging
0.0
MSS Blowdowns
5
9
2
5
75
0.0
Compressor Blowdowns (combined)
_
15
24
6
15
210
0.1
Compressor Venting
2
4
1
2
35
0.0
TOTAL (tpy)
16.7
1.8
1.1
75.2
85.1
20.1
38.6
10.8
0.5
0.1
0.0
0.0
250.1
'Total Reportable = all HAPs where uncontrolled emissions > de minimus values
Red Text: uncontrolled emissions < de minimus
emissions Wltn controls (los per year)
POINT PERMIT Description
I
Formaldehyde
Acetaldehyde
Acrolein
Benzene
Toluene
Ethyl....
Xylenes
n -Hexane
MCOH
034 r0'
H2S
TOTAL
OPY)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
19WE0171
Combustor for dehy waste streams
all HAPs de minimis for this point
0.0
002
19WE0171
TEG Dehy "D1"
1036
733
87
134
183
2
1.1
003
19WE0171
TEG Dehy "D2"
1036
733
87
134
183
2
1.1
004
GP02
Cat 63608 "See Note 1 below**
724
1224
753
64
60
6
27
163
366
37
1.7
005
GP02
Cat 63608 "See Note 1 below"
724
1224
753
64
60
6
27
163
366
37
1.7
006
GP02
Cat G3608 "See Note 1 below"
724
1224
753
64
60
6
27
163
366
37
1.7
APEN-Exempt / Insignificants
TEG Reboilers (2)
2
46
0.0
Slop Tanks (2 x 100 -bbl)
8
0.0
toadout of slop
1
12
0.0
Fugitive leaks
1
1
1
13
0.0
MSS Pigging
0.0
MSS Blowdowns
-
5
9
2
5
75
0.0
Compressor Blowdowns (combined)
15
24
6
15
210
0.1
Compressor Venting
2
4
1
2
35
0.0
TOTAL (tpy)
1.1
1.8
1.1
1.1
0.8
0.1
0.2
0.6
0.5
0.1
0.0
0.0
7.6
9
19WE0171.CP1
4/9/2019
illOA I q A ■ A !r\ A !\
DRAFT
VVIV J l IX V V I J. 1/41 rLru4IT
Permit number:
Date issued:
Issued to:
19WE0171
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General Description:
Issuance: 1
Rocky Mountain Midstream, LLC
Auburn Compressor Station
123/A02B
SEC 26 T5N R65W
Weld County
Natural Gas Compressor Station
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
C1
001
Enclosed combustor controlling emissions
from TEG dehydrators (Points 002 Et 003).
N/A
D1
002
One (1) triethylene glycol (TEG) natural
gas dehydration unit (make/model/serial
number: TBD) with a design capacity of
60 MMscf per day. This unit is equipped
with two (2) electric driven glycol pumps
(make, model: TBD) with a total design
capacity of 10 gallons per minute. This
emissions unit is equipped with a flash
tank, still vent, and reboiler burner.
Emissions from the still
vent are routed to an air -
cooled BTEX condenser,
and then to the enclosed
combustor (Point 001).
Emissions from the flash
tank are routed directly
to the enclosed
combustor (Point 001).
D2
003
One (1) triethylene glycol (TEG) natural
gas dehydration unit (make/model/serial
number: TBD) with a design capacity of
60 MMscf per day. This unit is equipped
with two (2) electric driven glycol pumps
(make, model: TBD) with a total design
capacity of 10 gallons per minute. This
Emissions from the still
vent are routed to an air -
cooled BTEX condenser,
and then to the enclosed
combustor (Point 001).
Emissions from the flash
tank are routed directly
COLORADO
Air Pollution Control Division
Department of Public Neatth & Environment
Page 1 of 14
emissions unit is equipped with a flash
to the enclosed
tank, still vent, and reboiler burner.
combustor (Point 001).
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 the specific general terms and conditions included in this document and the following
specific terms and conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
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, liy
submitting a Notice of Startup form to the Division for the equipment covered by this
permit. The Notice of Startup form may, be downloaded online at
www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup
of the permitted source is a violation of Air Quality Control Commission (AQCC)
Regulation Number 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. A self certification form and guidance on
how to self -certify compliance as required by this permit may be obtained online at
www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B,
Section 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. (Regulation Number 3, Part B, Section III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in
this permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The following information shall be provided to the Division within fifteen (15) days of
the latter of commencement of operation or issuance of this permit.
Point 001:
• The enclosed combustor make, model, and serial number.
Points 002 and 003:
• The dehydrator manufacturer name, model number and serial number; and
• The glycol circulation pump manufacturer name and model number.
This information shall be included with the Notice of Startup submitted for the
equipment. (Reference: Regulation Number 3, Part B, III.E.)
!COLORADO
Air Pollution Control Division
Department of Public. Health & Environment
Page 2 of 14
6. 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
7. Emissions of air pollutants shall not exceed the following limitations. (Regulation
Number 3, Part B, Section II.A.4.)
Monthly Limits:
Facility
Equipment
ID
AIRS
Point
Pounds per Month
Emission
Type
PM2.5
NO.
VOC
CO
C1
001
---
376
---
750
Point
D1
002
---
---
815
---
Point
D2
003
---
---
815
---
Point
Note: Monthly limits are based on a 31 -day month.
The owner or operator shall calculate monthly emissions based on the calendar month.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359
pounds per month.
Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds
per month.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all
permitted emission units at this facility.
Annual Limits:
Facility
ID
AIRS
Tons per Year
EmissionEquipment
Type
C1
001
-
2.2
---
4.4
Point
D1
002
---
---
4.8
---
Point
D2
003 _ _
---
---
4.8
---
Point
Note: See "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 not exceed 8.0
tons per year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per
year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all
permitted emission units at this facility.
COLORADO
Air Pollution Control Division
I Department of Pbakic Health & �.mPronmenx
Page 3 of 14
During the first twelve (12) months of operation, compliance with both the monthly and
annual emission limitations is required. After the first twelve (12) months of operation,
compliance with only the annual limitation is required.
Compliance with the annual limits, for criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at
a local field office with site responsibility for Division review.
8. Points 002 and 003: Compliance with the emission limits in this permit shall be
demonstrated by running the GRI-GLYCaIc model version 4.0 or higher for each
dehydrator on a monthly basis using the most recent extended wet gas analysis and
recorded operational values for each separate dehydrator, including: dry gas
throughput, lean glycol recirculation rate, condenser outlet temperature, flash tank
temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure.
Recorded operational values for each dehydrator, except for dry gas throughput, shall
be averaged on a monthly basis for input into the model and be provided to the Division
upon request.
9. Points 002 and 003: On a monthly basis, the owner or operator shall monitor and record
operational values for each TEG dehydration unit including: condenser outlet
temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet
gas inlet pressure. These records shall be maintained for a period of five years.
10. Points 002 and 003: For each dehydrator, the condenser outlet temperature shall not
exceed 125 degrees F, on a rolling twelve-month average. The owner or operator shall
calculate the rolling twelve-month average temperature by averaging all recorded
condenser outlet temperature values as specified in this permit.
11. The emission points in the table below shall be operated and maintained with the
emissions control equipment as listed in order to reduce emissions to less than or equal
to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.)
Facility
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
D1
002
Still Vent: BTEX Condenser, and Enclosed Combustor
(LEED EC48-2S L30-0035-000, sn: TBD)
VOC and
HAP
Flash Tank: Enclosed Combustor (LEED EC48-2S L30-
0035-000, sn: TBD)
VOC and
HAP
D2
003
Still Vent: BTEX Condenser, and Enclosed Combustor
(LEED EC48-25 L30-0035-000, sn: TBD)
VOC and
HAP
Flash Tank: Enclosed Combustor (LEED EC48-2S L30-
0035-000, sn: TBD)
VOC and
HAP
PROCESS LIMITATIONS AND RECORDS
12. This source shall be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rates shall be maintained by the owner or
COLORADO
Air Pollution Control Division
Department of lhablic Health 6 Environment
Page 4 of 14
operator and made available to the Division for inspection upon request. (Regulation
Number 3, Part B, II.A.4.)
Process Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Monthly
Limit (31
Ys)
C1
001
Waste gas combusted
21.27 MMscf
1.81 MMscf
Pilot and Purge gas
combusted
0.42 MMscf
0.04 MMscf
D1
002
Dry gas throughput
21,900 MMscf
1,860 MMscf
D2
003
Dry gas throughput
21,900 MMscf
1,860 MMscf
The owner or operator shall monitor monthly process rates based on the calendar month.
The volume of dry gas throughput shall be measured by gas meter at the outlet of the
dehydrator. The monthly volume of waste gas combusted shall be calculated from the
monthly GRI-GLYCalc model output.
During the first twelve (12) months of operation, compliance with both the monthly and
annual throughput limitations is required. After the first twelve (12) months of
operation, compliance with only the annual limitation is required.
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.
13. Points 002 and 003: Each unit shall be limited to the maximum lean glycol circulation
rate of 10.0 gallons per minute. The lean glycol recirculation rate shall be recorded
weekly in a log maintained on site and made available to the Division for inspection
upon request. Glycol recirculation rate shall be monitored by one of the following
methods: assuming maximum design pump rate, using glycol flow meter(s), or recording
strokes per minute and converting to circulation rate. This maximum glycol circulation
rate does not preclude compliance with the optimal glycol circulation rate (Lops)
provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4)
STATE AND FEDERAL REGULATORY REQUIREMENTS
14. The permit number and ten digit AIRS ID number assigned by the Division (e.g.
123/4567/001) shall be marked on the subject equipment for ease of identification.
(Regulation Number 3, Part B, Section III.E.) (State only enforceable)
15. 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. (Reference: Regulation No. 1, Section II.A.1. Et 4.)
16. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 5 of 14
17. Points 002 and 003: This source is subject to Regulation Number 7, Section XII.H. 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 glycol natural gas dehydrators; and
• Ensure uncontrolled actual emissions of volatile organic compounds from the
still vent and vent from any gas -condensate -glycol (GCG) separator (flash
separator or flash tank), if present, shall be reduced by at least 90 percent on
a rolling twelve-month basis through the use of a condenser or air pollution
control equipment. (Regulation Number 7, Section XII.H.1.)
18. Points 001, 002 and 003: 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.17, 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 control device must be
equipped with an operational auto -igniter upon installation of the combustion device.
19. Points 001, 002 and 003: The glycol dehydration unit covered by this permit is subject
to the emission control requirements in Regulation Number 7, Section XVII.D.3.
Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a
glycol natural gas dehydrator located at an oil and gas exploration and production
operation, natural gas compressor station, or gas --processing plant subject to control
requirements pursuant to Section XVII.D.4.,.shall reduce uncontrolled actual emissions
of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a
condenser or air pollution control equipment.
20. Points 002 and 003: The glycol dehydration unit at this facility is subject to National
Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and
Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable
area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and
HH. (Regulation Number 8, Part E, Subpart A and HH)
CDPHE
:COLORADO
Air Pollution Control Division
1 Depaeiment ccl RAbhc Health H Environment
Page 6 of 14
MACT HH Applicable
Requirements
Area Source
Benzene emissions exemption
§63.764 - General
Standards
§63.764 (e)(1) - The owner or operator is exempt from the
requirements of paragraph (d) of this section if the criteria listed
in paragraph (e)(1)(i) or (ii) of this section are met, except that
the records of the determination of these criteria must be
maintained as required in §63.774(d)(1).
§63.764 (e)(1)(ii) - The actual average emissions of benzene from
the glycol dehydration unit process vent to the atmosphere are
less than 0.90 megagram per year, as determined by the
procedures specified in §63.772(b)(2) of this subpart.
§63.772 - Test
Methods,
Compliance
Procedures and
Compliance
Demonstration
§63.772(b) - Determination of glycol dehydration unit flowrate or
benzene emissions. The procedures of this paragraph shall be
used by an owner or operator to determine glycol dehydration
unit natural gas flowrate or benzene emissions to meet the
criteria for an exemption from control requirements under
§63.764(e)(1).
§63.772(b)(2) - The determination of actual average benzene
emissions from a glycol dehydration unit shall be made using the
procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this
section. Emissions shall be determined either uncontrolled, or
with federally enforceable controls in place.
$63.772(b)(2)(i) - The owner or operator shall determine actual
average benzene emissions using the model GRI-GLYCaIc TM,
Version 3.0 or higher, and the procedures presented in the
associated GRI-GLYCaIc TM Technical Reference Manual. Inputs to
the model shall be representative of actual operating conditions
of the glycol dehydration unit and may be determined using the
procedures documented in the Gas Research Institute (GRI) report
entitled "Atmospheric Rich/Lean Method for Determining Glycol
Dehydrator Emissions" (GRI-95/0368.1); or
§63.772(b)(2)(ii) - The owner or operator shall determine an
average mass rate of benzene emissions in kilograms per hour
through direct measurement using the methods in §63.772(a)(1)(i)
or (ii), or an alternative method according to §63.7(f). Annual
emissions in kilograms per year shall be determined by
multiplying the mass rate by the number of hours the unit is
operated per year. This result shall be converted to megagrams
per year.
CDPHE
'COLORADO
Air Pollution Control Division
{ Department of RIblic Health & En.ronment
Page 7 of 14
$63.774 -
Recordkeeping
Requirements
§63.774 (d)(1) - An owner or operator of a glycol dehydration
unit that meets the exemption criteria in §63.764(e)(1)(i) or
§63.764(e)(1)(ii) shall maintain the records specified in paragraph
(d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for
that glycol dehydration unit.
563.774 (d)(1)(ii) - The actual average benzene emissions (in
terms of benzene emissions per year) as determined in
accordance with §63.772(b)(2).
OPERATING £t MAINTENANCE REQUIREMENTS
21. Points 002 and 003: Upon startup of these points, the owner or operator shall follow
the most recent operating and maintenance (O&tM) 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 the O&M plan are subject to Division
approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
22. Point 001: 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 XVII.B.2.
and XVII.A.17)
23. Points 002 and 003: The owner or operator shall complete the initial extended wet gas
analysis within one hundred and eighty days (180) of the latter of commencement of
operation or issuance of this permit. The owner or operator shall use this analysis to
calculate actual emissions, as prescribed in the Emission Limitation and Records section
of this permit, to verify initial compliance with the emission limits. The owner or
operator shall submit the analysis and the emission calculation results to the Division as
part of the self -certification process. (Reference: Regulation Number 3, Part B, Section
III.E.)
24. Points 001, 002 and 003: A source initial compliance test shall be conducted to
measure the emission rate(s) for the pollutants listed below in order to demonstrate
compliance with the emissions limits specified in this permit and to demonstrate a
minimum destruction efficiency of 98.0% for volatile organic Compounds (VOC). The
test shall determine the mass emission rates of VOC at the inlet and outlet of the control
device, which shall be used to determine the destruction efficiency during the test.
The test shall also determine the mass emission rates of oxides of nitrogen and carbon
monoxide during the test period. The gas throughput, lean glycol recirculation rate,
supplemental fuel flow rate and condenser outlet temperature shall be monitored and
recorded during the test.
The source shall use the measured outlet emission rates for VOC to demonstrate
compliance with the sum of the VOC emission limits specified in this permit for Point
002 and Point 003. The source shall use the measured outlet emission rates of oxides
COLORADO
Air Pollution Control Division
Department of Public Hearth & Environment.
Page 8 of 14
of nitrogen and carbon monoxide to demonstrate compliance with the emission limits
specified in this permit for Point 001.
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. (Regulation Number
3, Part B., Section III.G.3)
Volatile Organic Compounds using EPA approved methods
Oxides of Nitrogen using EPA approved methods
Carbon Monoxide using EPA approved methods
Periodic Testing Requirements
25. Points 002 and 003: The owner or operator shall complete an extended wet gas analysis
prior to the inlet of the dehydration unit on an annual basis. Results of the wet gas
analysis shall be used to calculate emissions of criteria pollutants and hazardous air
pollutants per this permit and be provided to the Division upon request.
ADDITIONAL REQUIREMENTS
26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part
A, II.C.)
• 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
COPHE
For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) 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.
• Whenever there is a change in the owner or operator of any facility, process, or
activity; or
• Whenever new control equipment is installed, or whenever a different type of
control equipment replaces an existing type of control equipment; or
'COLORADO
I Air Pollution Control Division
Department of Puhiie Health & Environment
Page 9 of 14
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
27. The requirements of Colorado Regulation Number 3, Part D shall apply at such time that
any stationary source or modification becomes a major stationary source or major
modification solely by virtue of a relaxation in any enforceable limitation that was
established after August 7, 1980, on the capacity of the source or modification to
otherwise emit a pollutant such as a restriction on hours of operation (Reference:
Regulation Number 3, Part D, V.A.7.B).
GENERAL TERMS AND CONDITIONS
28. 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 Number 3, Part B, Section II.B upon a request for transfer of ownership
and the submittal of a revised APEN and the required fee.
29. 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
Number 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.
30. 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.
31. 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.
32. 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.
33. 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
COLORADO
Air Pollution Control Division
Department of Kibbe Health & Environment
Page 10 of 14
Division in writing requesting a cancellation of the permit. Upon notification, annual
fee billing will terminate.
34. 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.
By:
Andy Gruel, P.E.
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Rocky Mountain Midstream, LLC.
COLORADO
Air Pollution Control Division
rmenf of Rabin Health Fr Emrrormen:.
Page 11 of 14
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. (Regulation Number 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.
Facility
Equipment
ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(lb/yr)
D1
002
Benzene
71432
75,078
1,036
Toluene
108883
85,032
733
Ethylbenzene
100414
20,084
87
Xylenes
1330207
38,539
134
n -Hexane
110543
10,398
183
2,2,4-
Trimethylpentane
540841
6
<1
D2
003
Benzene
71432
75,078
1,036
Toluene
108883
85,032
733
Ethylbenzene
100414
20,084
87
Xylenes
1330207
38,539
134
n -Hexane
110543
10,398
183
2,2,4-
Trimethylpentane
540841
6
<1
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission
rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees
based on the most recent Air Pollution Emission Notice.
CDPHE
COLORADO
Air Pollution Control Division
Department of Pubiic Health & EEnvironment.
Page 12 of 14
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
Emissions associated with this enclosed combustor result from the combustion of TEG
dehydrator still vent and flash tank waste gas (Points 002 a 003), purge gas, and pilot gas.
Total actual emissions are based on the sum of the emissions calculated for the combustion
of dehydrator waste gas (process 01) and the combustion of purge and pilot gas (process
02).
Process 01: Combustion of dehydrator waste gas (Flash tank and still vent from Point
002 & 003)
CAS #
Pollutant
Emission
Factors
Uncontrolled
lb/MMscf
Emission
Factors
Controlled
lb/MMscf
Source
NOx
208.530
208.530
TNRCC Flare
Emissions
Guidance
CO
416.304
416.304
Note: The uncontrolled VOC and HAP emissions from process 01 are reported with Point
002 and Point 003. NOx and CO emission factors are based on an average net heating value
of 1,511 Btu/scf based on waste stream composition calculated using GRI-GlyCalc 4.0 using
a non -site -specific representative facility inlet gas sample. Actual emissions are calculated
by multiplying the emission factors in the table above by the total gas flow (from Point 002
and 003) routed to this combustor as calculated in the monthly GlyCalc report required in
this permit.
Process 02: Combustion of purge and pilot fuel
CAS #
Pollutant
Emission "
Factors
Uncontrolled
lb/MMscf
Emission
Factors
Controlled
lb/MMscf
Source
NOx
177.744
177.744
TNRCC Flare
Emissions
Guidance
CO
354.844
354.844
Note: The emissions from combustion of purge and pilot fuel were calculated based on
plant residue gas heating value of 1,288 btu/scf, a purge rate of 4 scf/hr, and two (2) pilots
each rated at 22 scf/hr. Actual emissions are calculated by multiplying the emission factors
in the table above by the purge+pilot flow to the flare based on design rate (48 scf/hr).
Points 002 and 003:
The emission levels contained in this permit are based on information provided in the
application and the GRI GLYCaIc 4.0 model. Controlled emissions are based on a combustor
control efficiency of 98.0%.
Total actual VOC and HAP emissions for each point are based on the sum of the emissions
for the still vent and flash tank for each unit, as calculated on a monthly basis using GRI-
GLYCalc as specified in the permit. The secondary (combustion) emissions for Points 002
and 003 are reflected in the emission calculations for Point 001.
COLORADO
1 Air Pollution Control Division
Department of Public Health Er Environment
Page 13 of 14
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 permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration
unit and associated control device per the Colorado Oil and Gas Conservation Commission
rule 805b(2)(B) when applicable.
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC, CO, formaldehyde, benzene,
toluene, ethylbenzene, xylenes, n -hexane, and total HAPs
NANSR
Synthetic Minor Source of: VOC
MACT HH
Major Source Requirements: Not Applicable
Area Source Requirements: Applicable
NSPS 0000a
Area Source Requirements: Applicable
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
63A-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
!COLORADO
Air Pollution Control Division
1>eaanmenC of Public & Environment
Page 14 of 14
General APEN - Form APCD-200
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all
available APEN forms can be found on the Air Pollution Control Division (APCD) website
at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
AIRS ID Number: 123 /4-026 601
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 --Administrative Information _
Company Name1: Rocky Mountain Midstream, LLC
_ Site Name: Auburn Compressor Station Site Location: Section 26, Township 5N, R65W
Mailing Address: 3601 Stagecoach Road, Ste. 202
(Include Zip Code)
Longmont, CO 80504
Portable Source N/A
Home Base:
Site Location WeIA
ld
County:
NAICS or SIC Code: 213112
Contact Person: Matthew Norton
Phone Number: (817) 455-5799
E -Mail Address2: Matthew.Norton@williams.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
393470
Form APCD-2OO - General APEN - Revision 7/2018
gcer-ec zl15lig
p COLORADO
1IH.nlln b%nvn.u.me..l
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit tt and AIRS ID]
Section 2 - Requested Action
O NEW permit OR newly -reported emission source (check one below)
❑✓ STATIONARY source O PORTABLE source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment O Change company name3 O Add point to existing permit
❑ Change permit limit O Transfer of ownership4 O Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
❑ APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Combustor used to control emissions from
dehydrator flash tank and condenser vent streams
Manufacturer: Leed Model No.: EC48-2S L30-0035-000 Serial No.: TBD
Company equipment Identification No.
(optional):
For existing sources, operation began on:
Cl
For new or reconstructed sources, the projected start-up date is:
8/2019
O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day days/week weeks/year
Seasonal use percentage: Dec -Feb: Mar -May:
Form APCD-200 - General APEN - Revision 7/2018
Jun -Aug: Sep -Nov:
Awl, COLORADO
2 I �.mm.n �si�.nma"N,
nw i
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Processing/Manufacturing Information £t Material Use
0 Check box if this information is not applicable to source or process
From what year is the actual annual amount?
Design Process
Rate
(Specify: Units)
Actual Annual
Amount
(Specify Units)
Requested Annual
Permit Limits
(Specify Units)
Material
Consumption:`
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40°22' 15.00"N,104°37'45.00"W
❑ Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
discharge Height_
-Rate
1Telocit
operator
Stack lD No
Above Ground Level
Temp
Flow
(ACFM)
Y -
(ftlsec)
—( F)
Cl
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
® Upward
O Horizontal
❑ Downward
O Other (describe):
O Upward with obstructing raincap
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-200 - General APEN - Revision 7/2018 3 Ij'
,COLORADO
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Combustion Equipment £t Fuel Consumption Information
0 Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated
with this emission source)
Design. Input. Rate _
(MMBTU/hr)
Actual Annual Fuel Use
(Specify Units)
Requested Annual Permit Limits
(Specify Units)
5 :
3 3- 6
7 M Mscf/Yr
From what year is the actual annual fuel use data?
Indicate the type of fuel used6:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF)
❑✓ Field Natural Gas Heating value: 1415 BTU/SCF
❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon)
❑ Propane (assumed fuel heating value of 2,300 BTU/SCF)
o Coal Heating value: BTU/lb Ash content: Sulfur content:
El Other (describe): TEG Dehy Vapors Heating value (give units): 1409 BTU/scf flesh, 1829BTU/scf regenerator_
AAAA5 /1
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
11
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑✓ No
he control eouipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment .
Description `
Overall Collection Efficiency
Overall Control. Efficiency ...
(% reduction in emissions)"
TSP (PM)
PM10
PM2.5
SOX
NO),
CO
VOC
Other:
Form APCD-200 - General APEN - Revision 7/2018
COLORADO
4,oI.„,
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Pollutant
Uncontrolled
Emission
Factor
(Specify Units)
Emission
Factor
Source
(AP -42, Mfg.,
etc.)
Actual Annual Emissions
Requested Annual Permit --
Emission Limit(s 5
Uncontrolled
(tons/year)
Controlled
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year).
TSP (PM)
PM10
PM2.5
SOX
Gas Composition/ORE
0.0001
0.0001
NO.
0,138
RG-109
-14-x.2(
2:1"42.
CO
0.276
RG-109
4.e 4-4i
G'2
VOC
Gas Composition/ORE
0.0909
0.0909
Other:
it
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
N(
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
ng table to report the non -criteria pollutant (HAP) emissions from source:
Yes O No
CAS
Number
Chemical
Name
Overall
Control
Efficiency
Uncontrolled
---
Emission
Factor
(Specify Units)
Emission Factor
Source ,.
(AP -42, Mfg., etc.)
Uncontrolled
Actual
Emissions
(lbs/year)
Controlled
Actual
Emissions7
(lbs/year)
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-200 - General APEN - Revision 7/2018
� !COLORADO
5 1 CV:7J Of F..1":
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. -
nat(I re of Legally Authorized
',4//cr
Per
son g y (not a vendor or consultant) Date
A,(Gff14-3 �-L
Name (print)
Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
O Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-200 - General APEN - Revision 7/2018
6I
\ -y: CbOLORADO
L/J'YH WIn 6 Enn..cwni
Glycol Dehydration Unit APEN
Form APCD-202
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for glycol dehydration (dehy) units only. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-2OO) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: t1 'vi Li i AIRS ID Number: (23 /pi -0z8 /Qd2
[Leave blank unless APCD has already assigned a permit # and AIRS ID] _
Section 1 - Administrative Information
-Company Name':- Rocky Mountain Midstream, LLC
Site Name: Auburn Compressor Station
Site Location: Section 26 Township 5N, R65W
Mailing Address:
p Code)
3601 Stagecoach Road, Ste. 202
(Include Zip Code) g
Longmont, CO 80504
Site Location
County: Weld
NAICS or SIC Code: 213112
Contact Person: Matthew Norton
Phone Number: (817) 455-5799
E -Mail Address: Matthew.Norton@williams.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
333471 g.eceivtd 45111
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
COLORADO
1 I AV" ln:«��
xw�n a c�nwn-s�l
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment O Change company name3 O Add point to existing permit
❑ Change permit limit O Transfer of ownership4 ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
D Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info a Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Triethylene glycol dehydrator used to dehydrate natural gas
Company equipment Identification No. (optional): ID 1
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
8/2019
Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
Is this unit located at a stationary source that is considered
a Major Source of (HAP) Emissions?
hours/day
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
O
days/week
Yes
Yes
O
weeks/year
No
No
AV
COLORADO
2IA-M�wtllwTbEnelrcinnenl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS,ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer:
TBD
Dehydrator Serial Number: TBD
Model Number: TBD
Reboiler Rating: 1.5 MMBTU/hr
Glycol Used: 0 Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) 9 TriEthylene Glycol (TEG)
Glycol Pump Drive: ❑ Electric 0 Gas If Gas, injection pump ratio: / Acfm/gpm
Pump Make and Model: TBD
Glycol Recirculation rate (gal/min): Max: 10
Lean Glycol Water Content:
0.15
Wt.%
Requested: 10
# of pumps: 2
Dehydrator Gas Throughput:
Design Capacity: 60 MMSCF/day
Requested-: 21,900 MMSCF/year Actual: MMSCF/year
Inlet Gas: Pressure: 1098 psig Temperature: 80 ° F
Water Content: Wet Gas: lb/MMSCF ❑ Saturated Dry gas: 7.0 lb/MMSCF
Flash Tank: Pressure: 65 psig Temperature: 145 ° F ❑ NA
= Temperature: - ° F El NA
Cold Separator: Pressure: psig P
Stripping Gas: (check one)
9 None ❑ Flash Gas 0 Dry Gas 0 Nitrogen
Flow Rate:
scfm
Additional Required Information:
▪ Attach a Process Flow Diagram
❑� Attach GRI-GLYCaIc 4.0 Input Report Ft Aggregate Report (or equivalent simulation report/test results)
9 Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
COLORADO
,.m.f,I
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
0 Upward
❑ Horizontal
Section 5 - Stack Information
Geographical Coordinates
(LatitudeILongitude or UTM)
40°22'15.00"N,104°37'45.00"W
Dis (tar e Heigh
.,
a Ground Leve[
(feet) E
a
&rip
- yo-.
-.
Fla
�.
m
pe r ®ro
St ck I o a
f ! -
D1
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
O Upward with obstructing raincap
Indicate the stack opening and size: (check one)
Circular Interior stack diameter (inches): TBD
o Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Section 6 - Control Device Information
O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑✓ Condenser:
Used for control of: Regenerator
Type: BTEX
Make/Model:
Maximum Temp: 160 °F Average Temp: 125 °F
Requested Control Efficiency: 98 %
O VRU:
Used for control of:
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed:
Make/Model:
%
❑ Combustion
Device:
Used for control of: Condenser Vent & Flash Gas
Rating: 3.54 MMBtu/hr
Type: Combustor Make/Model: Leed EC48-23 L30-0035-000
Requested Control Efficiency: 98
Manufacturer Guaranteed Control Efficiency: 98 %
Minimum Temperature: °F Waste Gas Heat Content: Btu/scf
Constant Pilot Light: O Yes O No Pilot Burner Rating: .06 MMBtu/hr
Closed
• Loop
System:
Used for control of:
Description:
System Downtime:
%
O Other:
Used for control of:
Description:
Requested Control Efficiency:
0
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 4 I
COLORADO
Dcpartmonl.Patitc
en
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
fined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOx
NOx
CO
VOC
BTEX Condenser and Combustor
98%
HAPs
BTEX Condenser and Combustor
98%
Other:
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
•
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission mst s 5
i ( )
Uncontrolled
Basis
Units
Source "
1AP:42,
Mfg.;. etc.) -
Uncontrolled
_Emissions -
- ::(tons/pear) -
Controlled
;.Emissions 6
(tons/year):• .
Uncontrolled
Emtsstons, .
<.(tonsfyear):._.
Controlled '.::`:
.Emtssions,,:•
(torts%year)=..,-
- PM
SOX
NOx
CO
VOC
,33=65-3
Ib/MMSCF
GRI-GlyCalc
307.61
4,w51 Lt.(
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor .
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
3_- 2. 6
i 'Ms.
6 Ly(-/c,
Toluene
108883
3 ,Z3 63
(
Ethylbenzene
100414
O - 9 17-
/
7
Xylene
1330207
( -'7-6 O
n -Hexane
110543
b-43-5
//
2,2,4-
Trimethylpentane
540841
0 ;02.03
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
5 I A
COLORADO
x.:i: as i, f Pu .i
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. -
7t7
Signature f Legally Authorized Person (not a vendor or consultant)
it/o
Date
Name (print) Title
Check the appropriate box to request a copy of the:
Draft permit prior to issuance
E✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: / / www. colorado. goy /cd phe / apcd
COLORADO
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
Glycol Dehydration Unit APEN
Form APCD-202
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for glycol dehydration (dehy) units only. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: Iq WS- 0 I -I I AIRS ID Number: 123 ' froze> / Oro.,
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': -Rocky Mountain Midstream, LLC
Site Name: Auburn Compressor Station
Site Location: Section 26 Township 5N, R65W
lu Address:
p Code3601 Stagecoach Road, Ste. 202
(Include Zip Code) g
Longmont, CO 80504
Site Location
County: Weld
NAICS or SIC Code: 213112
Contact Person:
Phone Number:
E -Mail Address=:
Matthew Norton
(817) 455-5799
Matthew.Norton@williams.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
39.3471 eceiv-d,61 7_116 ill
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
1 I ACOLORADO
:- ;E^ �`"n,
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
❑� NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
o Change fuel or equipment O Change company name3 O Add point to existing permit
o Change permit limit ❑ Transfer of ownership4 O Other (describe below)
-OR -
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info £t Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Triethylene glycol dehydrator used to dehydrate natural gas
Company equipment Identification No. (optional): D2
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
8/2019
❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
hours/day days/week
Is this unit located at a stationary source that is considered
a Major Source of (HAP) Emissions?
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
a
Yes
Yes
weeks/year
No
No
,COLORADO
2 I _ mwwwc
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer: TBD
Dehydrator Serial Number:
TBD
Model Number: TBD
Reboiler Rating: 1.5 MMBTU/hr
Glycol Used: ❑ Ethylene Glycol (EG) O DiEthylene Glycol (DEG)❑ TriEthylene Glycol (TEG)
Glycol Pump Drive: ❑,r Electric O Gas If Gas, injection pump ratio:
Pump Make and Model: TBD
Glycol Recirculation rate (gal/min): Max: 10
Lean Glycol Water Content:
0.15
Wt.%
Requested: 10
Acfm/gpm
# of pumps: 2
Dehydrator Gas Throughput:
Design Capacity: 60 MMSCF/day
Requested5: 21,900 MMSCF/year Actual: MMSCF/year
Inlet Gas:
Water Content: Wet Gas:
Flash Tank: Pressure: 65 psig
Cold Separator: Pressure: psig
Stripping Gas: (check one)
0 None O Flash Gas O Dry Gas O Nitrogen
Pressure: 1098 psig Temperature: 80 .F
lb/MMSCF ❑✓ Saturated Dry gas: 7.0 lb/MMSCF
Flow Rate:
scfm
Temperature: 145 °F ❑ NA
Temperature:
of ❑ NA
Additional Required Information:
Attach a Process Flow Diagram
El Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results)
El Attach the extended gas analysis (including BTEX it n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
p COLORADO
3 I m4 !�lol�
HMlh 3Cnv:rvc�m.n1
0 Upward
O Horizontal
Permit Number:
AIRS ID Number: /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40°22'15.00"N,104°37'45.00"W
Operator
Stack ID No
Discharge Height
Above Ground Level
(feet)
Flow,,. Rate
(ACFM)
Velocity _.
�(ft%sec)
Temp
CF)
D1
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
O Downward
❑ Other (describe):
O Upward with obstructing raincap
Indicate the stack opening and size: (check one)
0 Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stag depth (inches):
❑ Other (describe):
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
DI Condenser:
Used for control of: Regenerator
Type: BTEX
Make/Model:
Maximum Temp: 160 F Average Temp: 125
Requested Control Efficiency: 98 °b
❑ VRU:
Used for control of:
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed:
Make/Model:
O Combustion
Device:
Used for control of: Condenser Vent & Flash Gas
Rating: 3.54 MMBtu/hr
Type: Combustor Make/Model:
Requested Control Efficiency: 98
Manufacturer Guaranteed Control Efficiency: 98
Leed EC48-2S L30-0035-000
Minimum Temperature: `F Waste Gas Heat Content: Btu/scf
Constant Pilot Light: 0 Yes O No Pilot Burner Rating: .06 MMBtu/hr
Closed
O Loop
System:
Used for control of:
Description:
System Downtime:
❑ Other:
Used for control of:
Description:
Requested Control Efficiency: %
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 4 I A_
COLORADO
DeAvceraiful of lvtu lll:
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOS
NO,,
CO
VOC
BTEX Condenser and Combustor
98%
HAPs
BTEX Condenser and Combustor
98%
Other:
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
.
Pollutant _
.
_
- : ----Emission Factor-- -- -
- —Actual Annual Emissions �--
Requested Annual. Permit
....._ E ._j.. ._:
m ssion_L mit(s)s::_r„_._.__
..._
Uncontrolled
Brits
._.__
Units
-.
•
rce, .
.: (AP 42,
-Mf3 , etc.)
.:`.Unconttolled._
Emissions-
(tons/year):...,
_.-., -
.:..:.:.
:.. Controlle _:
6....
Emissions ,--:
•... (tonslyear/
.•--. -: -.:.:. -
_,_UnconTrolled "�'.
;_ Emissions
'-,--(tonsl year)
. ..... __.-.-......
`-:.:Controlled :
:; Emissions : - -
(tons/ eidr) --',.
PM
SOx
NOS
CO
VOC
/
_33:69
lb/MMSCF
GRI-GlyCalc
307.61
4.,6Af"
Z5.0
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions 6
(pounds/year)
Benzene
71432
3 ,42. i
1514441_51
611 Cd I r
Toluene
108883
34g. 3 f .
Ethylbenzene
100414
Q7-
1
)
Xylene
1330207
I. 1-b0
n -Hexane
110543
U -'-(1-S•
2,2,4
Trimethylpentane
540841
c' 'v9' 3
5
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
51
f�/A iCOLORADo
S`a ecru nc� rtn.:
Hcpssr Serit m:nu::l
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
Signature of Legally Authorized Person (not a vendor or consultant) Date
C77-42-1/-\
t'1
Name (print)
Covy it/I/6
the appropriate box to request a copy of the:
El Draft permit prior to issuance
❑� Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: //www.colorado.qpv/cdphe/apcd
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
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