HomeMy WebLinkAbout20180086.tiffCOLORADO
Department of Public
Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150 O St
PO Box 758
Greeley, CO 80632
December 19, 2017
Sir or Madam,
RECEIVED
DEC 2 7 2017
WELD COUNTY
COMMISSIONERS
On December 21, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
Discovery DJ Services LLC — Discovery Oil Terminal. 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 & 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
Pc.);43 l ;c, Rem sz...v c.c.p LC crnM I TP) .
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2018-0086
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Discovery DJ Services LLC — Discovery Oil Terminal — Weld County
Notice Period Begins: December 21, 2017
Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado
Air Pollution Control Division for the following source of air pollution:
Applicant: Discovery DJ Services LLC
Facility: Discovery Oil Terminal
oil terminal
Section 25, T3N, R65W
Weld County
The proposed project or activity is as follows: oil terminal
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 17WE0964 have been filed
with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the
Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability of
the proposed project or activity to comply with the applicable standards and regulations of the Commission.
The Division will receive and consider written public comments for thirty calendar days after the date of this
Notice. Any such comment must be submitted in writing to the following addressee:
Kirk Bear
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
1
C LO
Permit number:
Date issued:
Issued to:
COLORADO
Air Pollution Control Division
Department of Public Health £r Environment
CONSTRUCTION PERMIT
17WE0964
Facility Name:
Plant AIRS ID:
Physical Location:
County:
Description:
Issuance: 1
Discovery DJ Services LLC
Discovery Oil Terminal
123 9F5D
Section 25, T3N R65W
Weld County
Transmission and Storage
Equipment or activity subject to this permit:
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
Tk-101
001
One 100,000 barrel external floating roof
storage tank
None
Tk-102
002
One 100,000 barrel external floating roof
storage tank
None
Tk-103
003
One 100,000 barrel external floating roof
storage tank
None
Tk-104
004
One 100,000 barrel external floating roof
storage tank
None
Tk-105
005
One 250,000 barrel external floating roof
storage tank
None
FUG
006
Equipment leaks from the facility
None
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
COLORADO
Air Pollution Corttrol Division,
Page 1 of 10
1. This construction permit represents final permit approval and authority to operate this emissions
source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.)
EMISSION LIMITATIONS AND RECORDS
2. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part
B, Section II.A.4.)
Annual Limits:
Facility
Equipment ID
AIRS
Point
Tons per Year _
Emission
Type
PM2.5
NO.
VOC
CO
Tk-101
001
--
--
12.8
--
Point
Tk-102
002
--
--
12.8
--
Point
Tk-103
003
--
--
12.8
--
Point
Tk-104
004
--
--
12.8
--
Point
Tk-105
005
--
--
17.6
--
Point
FUG
006
--
--
5.8
Facility
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.
Compliance with the annual limits, for both 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.
PROCESS LIMITATIONS AND RECORDS
3. 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 operator and made
available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.)
Process Limits
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Tk-1
001
Throughput
29,200,000 barrels
Landing Events
1
Cleaning Events
1
Tk-2
002
Throughput
29,200,000 barrels
Landing Events
1
,COLORADO
Air Pollution Control Division
1p*rt•r,,r,C C%i Pedd S Sestt..s ENirornnelt
Page 2 of 10
Cleaning Events
1
Tk-3
003
Throughput
29,200,000 barrels
Landing Events
1
Cleaning Events
1
Tk-4
004
Throughput
29,200,000 barrels
Landing Events
1
Cleaning Events
1
Tk-5
005
Throughput
29,200,000 barrels
Landing Events
1
Cleaning Events
1
The owner or operator shall monitor monthly process rates based on the calendar month.
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.
STATE AND FEDERAL REGULATORY REQUIREMENTS
4. Point 001, 002, 003, 004, 005: 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)
5. Point 001, 002, 003, 004, 005, 006: This source is subject to the odor requirements of Regulation
Number 2. (State only enforceable)
6. Point 001, 002, 003, 004, 005: This source is subject to the applicable requirements of Regulation
Number 7, Section VI.B.2.
7. Point 001, 002, 003, 004, 005: This source is subject to the New Source Performance Standards,
Standards of Performance for Volatile Organic Liquid Storage Vessels for which construction,
reconstruction or modification commenced after July 23, 1984, Subpart Kb. This facility shall be
subject to all provisions of this regulation, as stated in 40 C.F.R Part 60, Subparts A and Kb.
(Regulation Number 6, Part A, Subparts A and Kb).
8. Point 006: Visible emissions shall not exceed twenty percent (20%) opacity during normal
operation of the source. During periods of startup, process modification; or adjustment of control
equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty
consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or
XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.)
9. Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise
not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply. Reasonably Available
Control Technology for the pollutants for which the area is nonattainment or
attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). Directed Inspection &
Maintenance (DI&M), as required by this permit, shall satisfy the requirement to apply Reasonably
Available Control Technology (RACT).
10. Minor sources in designated nonattainment or attainment/maintenance areas that are
otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply
COLORADO
Air Pollution Control Division
Pubikt i ealt5,. s E-rrir-Onmea
Page 3 of 10
Reasonably Available Control Technology (RACT) for the pollutants for which the area is
nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B,
III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the
following emission controls:
a. Directed Inspection & Maintenance as described below shall satisfy the
requirement to apply RACT.
i. Auditory/visual/olfactory inspection (AVO) will be performed on a
quarterly basis.
ii. For each leak found in the AVO inspection, a gas detector may be used
to determine the size of the leak. The gas detector shall be regularly
calibrated. Component leaks greater than 10,000 ppm shall be
managed in accordance with Item (vi) below, unless it is unfeasible to
make the repair without shutting down the affected operation of the
facility. Component leaks less than 10,000 ppm shall not require repair.
For such component leaks that require a shutdown to be repaired,
repair shall occur during the first shutdown of the affected operation
after the leak is discovered.
iii. For repair, valves adjacent to the equipment to be repaired will be
closed if practicable, minimizing the volume released.
iv. Repaired components shall be re -screened using AVO to determine if
the leak is repaired.
v. The following records shall be maintained for a period of two years:
• The name of the site screened via AVO inspection and the
name of the inspector.
• Components evaluated with the gas detector.
• Repair methods applied.
• Dates of the AVO inspections, gas detector calibrations,
attempted repairs, successful repairs, repair delays, and post -
repair screenings.
vi. Leaks shall be repaired as soon as practicable, but no later than 15
calendar days after detection, unless it is technically or operationally
infeasible to make the repair within 15 calendar days. Records
documenting the rationale shall be maintained if it is technically or
operationally infeasible to make the repair within 15 calendar days.
OPERATING & MAINTENANCE REQUIREMENTS.
11. Upon startup of these points, the owner or operator shall follow the most recent operating and
maintenance (O&M) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to
your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation
No. 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Periodic Testing Requirements
;COLORADO
Air Pollution Control Division
Page 4 of 10
12. Point 006: On an annual basis, the owner or operator shall complete an extended gas analysis of
gas samples that are representative of volatile organic compounds (VOC) and hazardous air
pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be
used in the compliance demonstration as required in the Emission Limits and Records section of
this permit.
ADDITIONAL REQUIREMENTS
13. 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
For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone
nonattainment areas emitting less than 100 tons of VOC or NO,t 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
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
GENERAL TERMS AND CONDITIONS
14. 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.
15. 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.
16. 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.
}COLORADO
Air Pollution Control Division
C' Pub Health 6 E;v gmment
Page 5 of 10
17. 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.
18. 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.
19. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission
Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a
source or activity is to be discontinued, the owner must notify the Division in writing requesting a
cancellation of the permit. Upon notification, annual fee billing will terminate.
20. 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:
Kirk Bear
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Discovery DJ Services LLC
COLORADO
llotion Control Division
Page 6 of 10
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.
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(Ib/yr)
001
Benzene
71432
38
Toluene
108883
25
Ethylbenzene
100414
3
Xylenes
1330207
3
n -Hexane
110543
261
224 TMP
540841
24
002
Benzene
71432
38
Toluene
108883
25
Ethylbenzene
100414
3
Xylenes
1330207
3
n -Hexane
110543
261
224 TMP
540841
24
003
Benzene
71432
38
Toluene
108883
25
Ethylbenzene
100414
3
Xylenes
1330207
3
n -Hexane
110543
261
224 TMP
540841
24
COLORADO
Air Pollution Control Divis
nepottot0t 0r :bit t tea trk & E—»ir, r r
Page 7 of 10
004
Benzene
71432
38
Toluene
108883
25
Ethylbenzene
100414
3
Xylenes
1330207
3
n -Hexane
110543
261
224 TMP
540841
24
005
Benzene
71432
78
Toluene
108883
52
Ethylbenzene
100414
7
Xylenes
1330207
6
n -Hexane
110543
551
224 TMP
540841
50
006
Benzene
71432
44
Toluene
108883
111
Ethylbenzene
100414
49
Xylenes
1330207
49
n -Hexane
110543
301
224 TMP
540841
87
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per
year ( b/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission
Notice.
5) The emission levels contained in this permit are based on the following emission factors and were then
combined with landing and cleaning event emissions outlined in the preliminary analysis:
Points 001, 002, 003, 004:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Source
VOC
0.000615
EPA Tanks
71432
Benzene
0.0000009020
EPA Tanks
108883
Toluene
0.0000005860
EPA Tanks
100414
Ethylbenzene
0.0000000785
EPA Tanks
1330207
Xylene
0.0000000668
EPA Tanks
110543
n -Hexane
0.0000063000
EPA Tanks
540841
224 TMP
0.0000005730
EPA Tanks
Point 005:.
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl -
Source
VOC
0.000564
EPA Tanks
71432
Benzene
0.0000012600
EPA Tanks
108883
Toluene
0.0000008190
EPA Tanks
!COLORADO
i Air Pollution Control Division
Page 8 of 10
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Source
100414
Ethylbenzene
0.0000001110
EPA Tanks
1330207
Xylene
0.0000000923
EPA Tanks
110543
n -Hexane
0.0000088100
EPA Tanks
540841
224 TMP
0.0000008010
EPA Tanks
Point 006:
Component
Gas Service
Heavy Oil
Light Oil
SWater/Oil
ervi
Service
Connectors
52
Flanges
220
Open-ended Lines
0
Pump Seals
18
Valves
104
Other*
9
VOC Content
0.9992
Benzene Content
0.0038
Toluene Content
0.0096
Ethylbenzene
0.0043
Xylenes Content
0.0043
n -hexane Content
0.0260
*Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains,
dump arms, hatches, instrument meters, polish rods and vents
TOC Emission Factors (kg/hr-component):
Component
Gas Service
Heavy Oil
Light OH.
Water/Oil
Service
Connectors
2.0E-04
7.5E-06
2.1E-04
1.1E-04
Flanges
3.9E-04
3.9E-07
1.1E-04
2.9E-06
Open-ended Lines
2.0E-03
1.4E-04
1.4E-03
2.5E-04
Pump Seals
2.4E-03
NA
1.3E-02
2.4E-05
Valves
4.5E-03
8.4E-06
2.5E-03
9.8E-05
Other
8.8E-03
3.2E-05
7.5E-03
1.4E-02
Source: EPA -453/R95-017
Compliance with emissions limits in this permit will be demonstrated by using the TOC emission
factors listed in the table above with representative component counts, multiplied by the VOC content
from the most recent gas analysis.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the
most recent annual fee invoice to determine the APEN expiration date for each emissions point
OLORADO
Air Pollution Control Division
; ,era st i4 tom;
Page 9 of 10
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 storage tank and associated
control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when
applicable.
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
True minor source of: VOC and HAP
NANSR
True minor source of: VOC and HAP
Kb
Applicable
MACT HHH
Not 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
63.1-63.599
Subpart A — Subpart Z
MACT
63.600-63.1199
Subpart AA — Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ — Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ —Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN — Subpart XXXXXX
,COLORADO
I Air Pollution Control Division
:.r,t,,+Yoa:x�zri
Page 10 of 10
Colorado Air Permitting Project
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
Section 01 - Facility Information
Kirk Bear
368443
8/29/Z01
x/2017
Company Name: Discovery Di Services
County AIRS ID: 123
Plant AIRS ID: 9F50
Facility Name: Discovery :Off :Terminel,,
Physical. Address/Location: Section 25, Township 3N, Range 65WW, in Weld County, Colorado
Type of Facility: Oil Storage and Pipeline injection
What industry segment? Natural- Gas Transmission &Storage
Is this facility located in a NAAQS non -attainment area? Yes
If yes, for what pollutant? carbon Monoxide (CO) Particulate Matter (PM) Ozone (NOx & VOC)
Weld
Quadrant
Section
Township
Range
65W
Section 02 - Emissions Units In Permit Application
AIRs Point #
Emissions Source Type
Equipment
Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Crude Oil Tank
Tk-101
No,
17WE0964
1
Yes
Permit Initial
Issuance2 ,.
003
,
004
005
006
007
Section 03 - Description of Project
The permit for this oil terminal will include the installation of an 50,000 barrels per day (29,200,000 barrels per year) crude oil storage facil ity_ Equipment for the
termianal will include above ground storage tanks and a pipeline pig launcher and reciever area. The terminal will contain the following emission sources:
two 250,000 barrel EFR stoarage tanks
three 100,000 barrel EFR storage tanks
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why?
6
yes
Store pery
Section 05 - Ambient Air Impact Analysis Requirements
Was a quantitative modeling analysis required?
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Non -Attainment Area
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
Colorado Air Permitting Project
If yes, indicate programs and which pollutants:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
Is this stationary source a major source?
If yes, explain what programs and which pollutants here:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
❑ ❑ ❑ ❑ O O
O O O O O O O
O O
SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
O O. O O O O
O. O O O O O O O
O ❑
Condensate Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
Facility AIRS ID:
County Plant
Poin
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control
Efficiency °A:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions- Storage Tank(s)
Actual Throughput =
Requested Permit Limit Throughput =
Barrels (bbl) per year Actual Crude Oil Throughput While Emissions Controls Operating =
Barrels (bbl) per year
Potential to Emit (PTE) Throughput= l P" `2P,2OI DO Barrels (bbl) per year
Secondary Emissions - Combustion Device(s)'
Heat content of waste gas=
,..,.(>j� Biu/scf
Volume of waste gas emitted per BBL of liquid
produced = cf/bbl
Actual heat content of waste gas routed to combustion dvice
Requested heat content of waste gas routed to combustion device =
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
0 MMBTU per year
0 MMBTU per year
0 MMBTU per year -
Emission Factors
Crude Oil Tank
Uncontrolled Controlled
Pollutant
VOC
Benzene
Toluene
(lb/bbl)
(Crude Oil
Throughput)
3OQO564O011O,"
:',400000.13i40.W.
(Ib/661)
(Crude Oil
Throughput)
0.000564
0.000001
0.000001
0.000000
0.000000
0000009
0,000001
Ethylbenzene
Xylene
n -Hexane
224TMP
Pollutant
Control Device
Uncontrolled
(lb/bbl)
(Crude Oil
Throughput)
Uncontrolled
(Ib/MMBtu)
(waste heat
combusted)
PM10
PM2.5
NOx
CO
Section 05 - Emissions Inventory
Emission Factor Source
Emission Factor Source
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tans/year) (tons/year)
VOC
PM10.
PM2.5
NOW
Co
8.2
8.2
8.2
8.2
8.2
0.0
0.0
0.0
0.0
0.0-
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
37
37
37
37
37
24
24
24
24
24
3
3
3
3
3
3
3
3
3
3
257
257
257
257
257
23
23
23
23
23
Section 06 - Regulatory Summary Analysis ,
Regulation 3, Parts.A,B
Regulation 7, Section XVI LB, C.1, C.3
Regulation 7, Section XVII.C(2
Regulation 6, Part A, NSPS Subpart Kb
Regulation 6, Part A, NSPS Subpart 0000
Regulation 8, Part E, MACT Subpart HH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Storage Tank is not subject to Regulation 7, Section XVII
Storage Tank is not subject to Regulation 7, Section XVII.C.2
Storage tank is subject to NSPS Kb
Storage Tank is not subject to NSPS 0000
Storage Tank is not subject to MACE Nil
Section 07 - Initial and Periodic Sampling and Testing Requirements
9.4000
9.4000
9.4000
9.4000
9.4000
9.4000
total with landings
17.6
00022 0.02068 41.36
0.0015 0.0141 2
0.0002 0.00188 3.76
0,0002 0.00188 3.7
0.0156 0.14664 293.28
00014 0.01316 26.32
9.4
3 of33
K:\PA\2017\17 W E0964.CP1:xlsm.
Condensate Storage Tank(s) Emissions Inventory
Does the company use the state default emissions factors.to estimate emissions?
If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 20 tons VOC per year?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 1403
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurizedliquid sample of crude oil drawn at the
facility being permitted?
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
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 Rates
��a��� m Ht�ana}ysisare thc9anding io
AIRS Peint#
004
Section 09 - Inventory 5CC Coding and Emissions Factors
Process # 5CC Code
01
Uncontrolled
Emissions
Pollutant Factor Control% Units
PM10 0.00 0 lb/1,000 gallons crude oil throughput
PM2.5 0.00 0 lb/1,000 gallons crude oil throughput
NOx 0.00 0 lb/1,000 gallons crude oil throughput
VOC 0.0 0 16/1,000 gallons crude oil throughput
CO - 0.00 0 lb/1,000gallonscrude oil throughput
Benzene 0.00 0 16/1,000 gallons crude oil throughput
Toluene 0.00 0 16/1,000 gallons crude oil throughput •
Eshylbenzene 0.00 0 16/1,000 gallons crude oil throughput -
Xylene 0.00 0 16/1,000 gallons crude oil throughput -
n -Hexane 0.00 0 lb/1,000 gallons crude oil throughput
224 TMP 0.00 0 16/1,000 gallons crude oil throughput
4 of 33 K:\PA\2017\17WE0964.CP1.xlsm
Crude Oil Storage Tank Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - OPEN end Permit Regylrements
Ynu' have lhdlatedshaesaume la in he NomAttolnment Area
arrqumBiT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TP( (Regulation 3, Parte., Sem'on 11.0.1.e)7
2 is the construction date prior to 4/14/2034 and trot modified after4/14/14 (See PS Meow ]4-03 for additional guidance on grandfather applicability)?
2a. If answer tog2ls yes, Is the crude oil throughput less than 40,000 gallons per year?
3. Aretotal facllityurcontrolledVOCemissions greater than Toy, "lox greater0an10TPY or CO emissions greeter Man 10 TM( (Regulation 3, Part B,Section 11.0.317
Il'au i;uuutudicated;hattnr1tr &BatenlanAtaim. ,nArea
NON -ATTAINMENT
L Are uncontrolledemisslons from any criteria pollutants from this individual source greater than l IP?(Regulation 3, Part A, Section 11.0.1.°)?
2. Is the construction date priori 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on gran dfatherapplloabilityl?
2a. If answer to d2 Is yes, is the crude oil throughput less than 40,000 gallons per year?
3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOs greater than 5TPY or CO emissions greater then 5 TPY (Regulation 3, Part B, Section 1122)?
gene requirasa pernft
Colorado Regulation 7, Section XVII
1. Is this tank located et a transmission/storage fadlltyl
2. Is this crude oil storage lank' located at an oil and gas exploration and production operation , welhproductian fadlltVt, natural gas compressor station'or natural gas processing plant?
3. Is this crude all storage tank a fixed roof storage tank?
4. Preunwntrolled actual emissi00seof Ws stoage tank equal to or greater lbw.tons per year VOC?
IS.ruge Took lerof vobicrrfn Itng:dailun 7, Sca lion XVII
Sectlon XVII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Sectlon XVII.C3-Emissions Control and Monitoring Provisions
Sectlon XVll,O3 - Recordkeeping Requirements
5. Does the crude oil storage tank contain onlystabllired' liquids? If, the following eddtuanalptoe'done apply.
I Storage Tank Is not 4ublectto t nula00n 7, .Sec00n X111.22
Section XVII.C.1 -Capture and Monitoring tor StorageTenks fitted with Air Pollution Control Equipment '
40 ffR, Part BO. Subvert Kb, Standards of Performance for Volatile Oraano trouts' storage Vessels
is the individual storage vessel rapacity greater Manor equal to 75 cubic meters (ma( (`472 Ms)?
2. Does the storage vessel meet the following exemption In 60.111b(dl(41?
a. Does the vessel has a deslgnrapacity less Manor equal to 1,5897374 m'(-So,000 BBL] used for petroleum'or condensate stored,processed, or treated prier to custodytransfers as defined In 60.1116?
3. Was this Condensate storage tank nano acted, reconstructed, or modified late definitiara40 CFR, 60.21 afterluly 23, 19B4?
9. Does the tank meet the definition of "storage vessela' In 60.1116?
5. Does the storage vessel store a"volatile organic liquid(VOLI' as defined in 60.1116?
6. Does the storage vessel meet anyone At me following addtlonalexemptions(
a. Is the storage vessel a pressure vessel designed to operate In excess 0(204.5 kPa ("29.7 psi] end without emissions to the atmosphere (60.110bld1(211tI or
b. The design capacity Is greater than or equel to 151 mt4,50 BBL] and storm a liquid with a maximum true vapor pressure less than 3.5 kPa (60.110blbR?i or
c. The design capacity Is greater than or equal to 75 Mr ('472 got] but less than 151 mt i"050 BBL] and stores a liquid with a maximum true vapor pressures less than 15.0 kPa(60.110b(bll?
IStornnn faek Ie NANA, N6p6 Xh
SubpartA, General Provisions
46o.112b- Emissions Control Standards for VOC
§60.1136 -Testing and Procedures
§50.113b- Reporting and Recordkeeping Requirements
56o.116b- Monitoring ofOperations
40 CPR, Part60 Seboart0000 Standards ofPerformense for Crude Deans( Nature] Gas Production. Transmission and Dbtribu0on
1. Is this crude oil storage vessel located ate facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry?
2. Was this crude all storetevessel constructed,reconstructed, or modeled (see definitions 40 CFR,60.2) between August 73, 2011 and September 15, 2o15?
3. Are potential VOC emissions' from the individual storage vessel greater than or equal too tons per year?
4. Does this crude oil storage vessel meet the definition of "storege vessel"t er60.54307
to ISag0 Took Is Oaths lmito NSPB 0000
SubpartA, General Provisions per 560.5925 Table 3
460.5395- En&slons Control Standards for VOC
550.5413 -Testing and Procedures
460.53951gl-Notification, Reporting and Recordkeeping Reglltement5
46D.naeo(o)-Cover and Closed Vent System Monitoring Requiemena
460.5417 -Control Device Monitoring Requirements
(Note: If storage vessel Is previously determined to be cublectt0 MPS 0000 due. emissions above Storrs par year VOConWe applicability determination date, It should remain subject. NSPS 0000 per6D.53eolsl(S)
PORK potential VOL omissions drop below 9 -tons per pearl
90 CFR, Part 03. Soho.. MACr HFI, 'Mend Gas Production facilities
a. Is me storage tank located at an oll and natural gas production faclllty thatmeeo e,the following criteria:
a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.76n(al(2)lr OR
b. Afacility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category oris delloored to a final end users (63.76ole((3)1?
L Is the tank located at a facility Met a major' for HAP'?
3, Does the tank meet the definitionof"storage vessel"a in 63.761?
9. Ices the tank meet the definition of"staage vessel with the potential for Rash emissions"' per 63.7617
S. a the tank subject to control requirements under 90 CPR Pert 60, Subpart II or Subpart 0000?
(Storage Tani i1 rwtee4jeratn MACTr:i
SubpartA, General provisions per §05.754 (al Table 2
463.766 -Emissions Control Standards
Pens Monitoring
§et,004-Recordkeeping
469.775 -Reporting
RAU Review
RACTrevlew le required If Regulation>does not apply Pilo if the tank Is in the nonatalnment area. If the lank meets barn criteria, then review RACE requirements.
Disclaimer
Yea
Source flequlresan OPEN. Go to the next question
Go w next question
Source Requires a permit
Source Is notsubject to provisions of Regulation 7, Section XVII-You have indicated the source category on hie Project summary sheet.
Storage Tank is net subject to Regulation 7, section XVII - It does not meet the storage tank definition. You have indicated the facility type on the Project summary sheet.
Storage Tank is not subject to Regulation 7, Sectlon XVI1
Storage Tank is twtsubfect to Regulation 7, Section XVII.C.2
Go to the next question
o to the next question
Gn to the next question
Go to the next question
Go to the next question
Source Is subject to NSPS k6
lAGll ''ii'd''�t
1 kPa = 5.1450377300D) psi
1 kpa=0.145037730007 psi
Continue -You have Indicated the source category on the Projectsummary sheet.
Storage Tank Is not subject PAPS 0000 -This tank was constructed prior to the applicability date.
Go to the next question
INo IThefacllltyls not an affected source under MALT HH - You have lndlated the source category on the Protect Summary sheet
Yes
Thk docurn nl assists operators with determining applicability of certain requirermnts of the Clean Air Act, its Implementing regulations, and Alr Quality Control Commksion rogulatlons. This docdrnentis not
a role or regulation, and the anaysis it contains may not apply to a particular sduslnd based upon the Individual facts and circumstances, This document does not change or substitute for any law, regulation,
or any other legal& binding requirement and is not legally enforceable. In the event of any conflkt behveen the language ofthls document and the language of the Clean Ai Act„ Ms Implementing regulations,
andAk. Quality Control Commission regulations, the language ofthe statute orregulatlan will conboL The use of nommandatorylanguege such as "recommend,^array.""should,"end "can,"k Mended to
desq'5e ApCo Mferpretedons and reconunendatons. Mandatory tannhology such as "must" and `requked` are Hondato describe csMrollhg requirements under the terms of the Clean Ak Act and Ale
Quaky Control Conanksbn regulations, but this document does not establish Jaggy binding requkements hand of bah'.
oeflnieons forprop pawn WK
Crude Oil Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
'Facility AIRs ID:
• 123
County
Plant
Point
Section 02- Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description: _
Requested Overall VOC& HAP Control
Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Throughput=
Requested Permit Limit Throughput =
Potential to Emit (PTE) Throughput=
Barrels (bbl) per year Actual Crude Oil Throughput While Emissions Controls Operating =
Barrels (bbl) per year
Barrels (bbl) per year
Secondary Emissions- Combustion Device(s)
Heat content of waste gas= 33i�11Ilii Btu/scf
Volume of waste gas emitted per BBL of liquids
produced =
scf/bbl
Actual heat contentof waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
0 MMBTU per year
0 MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
Pollutant
Uncontrolled
Controlled
(lb/bbl)
(Ib/bbl)
(Crude Oil
Throughput)
0:0006150000 -i
0001000: 11
. '`q.RODRD05860g'*3
ID0078 ^7.
630:
(Crude Oil
Throughput)
0.000615
0.00000
0.000001
0.000000
0.000000
0.000006
0.000001
Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu)
(waste heat
combusted)
(lb/bbl)
,,,.,..,,,,,,,,,,,,,,:.1
(Crude Oil
Throughput)
0.0000
0.0000
0.0000
0.0000
Emission Factor Source
Emission Factor Source
Section 05 - 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)
VOC
PM10
PM2.5
NOx
CO
9.0
9.0
9.0
9.0
9.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual missions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
5 -Hexane
224 TMP
26
26
26
.. 26
26
17
17
17
17
17
2
2
2
2
2
2
2
2
2
2
184
184
184
184
184
17
17
17
17
17
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A,B
Regulation 7, Section XVII.B, Cl, C.3
Regulation 7, Section XVII.C.2
Regulation 6, Part A, NIPS Subpart Kb
Regulation 6, Part A, NIPS Subpart 0000
Regulation 8, Part E, MACE Subpart HH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Storage Tank is not subjectto Regulation 7, Section XVII
Storage Tank is not subject to Regulation 7, Section XVII.C.2
Storage tank is subject to NSPS Kb
Storage Tank is not subject to NIPS 0000
Storage Tank is not subject to MACE HH
Section 07- Initial and Periodic Sampling and Testing Requirements
3.8000
3.8000
3.8000
3.8000
3.8000
3.8000
Does the company use the state default emissions factors to estimate emissions?
If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 20 tons VOC per year?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03
5.0015 0!0057 11.4
0.0010 0(0038 7.6'd
0.0001 04)0038 0.76)
0.0001 0.00038
0.0102 0.03876 77.52:
0.0009 0.00342
6.84'
3.8
7 of 33 K:\PA\2017\17 W E0964.CP1.xism
Crude Oil Storage Tank(s) Emissions Inventory
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample of crude oil drawn at the
faciity being permitted?.;,
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
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
nd# inoudA In this afvlyoisSrethe landing lee?
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point #
001
Process #
01
SCC Code
Definitions for Drop Down Lists
Storage Tank Emissions Factor Options
Crude Oil State E.F. (includes flash)
Site Specific E.F. (includes flash)
Site Specific EPA TANKS E.F. Working and Breathing Only
Other (Documented in Technical Analysis Notes)
Qualifiers
No
Yes
Not applicable - stabilized tank
Control Devices
Enclosed Flare
Open Flare
Vapor Recovery Unit (VRU)
Control Device Combustion Emissions Factor Options
NOx CO PM
AP -42 Chapter 13.5 Industri AP -42 Chapter 13.5 AP -42 Table 1.4-2 (PM10/PM.2.5)
TNRCC Flare Emissions Guid TNRCC Flare Emissic Other- Explain
AP -42 Table 1.4-1(NOx) AP -42 Table 1.4-1(CO)
Other- Explain Other- Explain
so: Codes - Storage Tank Emissions
4-04-003-12 Fixed Roof Tank, Crude Oil, working+breathing+flashing losses
4-04.003-02 Fixed Roof Tank: Working & Breathing Losses
4-04-003-22 External Floating Roof Tank, Crude Oil, working+breathing+flashing
4-04-003-06 External Floating Roof Tank: Working and Breathing Losses
4-04-003-321ntemal Floating Roof Tank, Crude Oil, working+breathing+Bashing
4-04-003-07 Internal Floating Roof Tank: Working and Breathing Losses
so: Codes - Flaring Combustion Emissions
3-10-001-60 Flares
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 0.00 0 lb/1,000 gallons crude oil throughput
PM2.5 0.00 0 lb/1,000 gallons crude oil throughput
NOx 0.00 0 lb/1,000 gallons crude oil throughput
VOC 0.0 0 lb/1,600 gallons crude oil throughput
CO 0.00 0 lb/1,000 gallons crude oil throughput
Benzene 0.00 0 Ib/1,000 gallons crude oil throughput
Toluene 0.00 0 lb/1,000 gallons crude oil throughput
Ethylbeneene 0.00 0 lb/1,000 gallons crude oil throughput
Xylene 0.00 0 Ib/1,000 gallons crude oil throughput
n -Hexane 0.00 0 lb/1,000 gallons crude oil throughput
224 TMP 0.00 0 lb/1,000 gallons crude oil throughput
8 of 33 K:\PA\2017\17W E0964.CP1.xism
Crude Oil Storage Tank Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
IYou have indicated that source is in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the construction date prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)?
2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year?
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section I I.D.3)?
'You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1.' Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the construction date prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)?
2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year?
3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section ll.D.2)?
'Source regtdre's a permit
Colorado Regulation 7, Section XVII
1. Is this tank located at a transmission/storage facility?
2. Is this crude oil storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station or natural gas processing plant?
3. Is this crude oil storage tank a fixed roof storage tank?
4. Are uncontrolled actual emissions' of this storage tank equal to or greater. than 6 tons per year VOC?
IStorage Tank is not subject to Regulation 7, Section XVII
Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.C.1 - Emissions Control and Monitoring Provisions
Section XVII.C.3 - Recordkeeping Requirements
5. Does the crude oil storage tank contain only "stabilized" liquids? If no, the following additional provisions apply.
'Storage Tank is not subject to Regulation 7, Section XVILC,2
Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
40 CFR, Part 60, Subpart Kb. Standards of Performance for Volatile Organic Liquid Storage Vessels
1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m3) (-472 BBLs]?
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)?
a. Does -the vessel has a design capacity less than or equal to 1,589.874 m3 [-10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.111b?
3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984?
4. Does the tank meet the definition of "storage vessel"3 in 60.1116?
5. Does the storage vessel store a "volatile organic liquid (VOL)"5 as defined in 60.1116?
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa ("29.7 psi] and without emissions to the atmosphere (60.11ob(d)(2))?; or
b. The design capacity is greater than or equal to 151 m3 (-950 BBL] and stores a liquid with a maximum true vapor pressures less than 3.5 kPa (60.110b(b))?; or
c. The design capacity is greater than or equal to 75 M3 ["472'BBL] but less than 151 m5 [-950 BBL] and stores a liquid with a maximum true vapor pressures less than 15.0 kPa(60.110b(b))?
Storage tank is subject to NSPS Kb
Subpart A, General Provisions
§60.112¢ - Emissions Control Standards for VOC
§60.113b - Testing and Procedures
§60.1156\ Reporting and Recordkeeping Requirements
§60.116b - Monitoring of Operations
40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
1. Is this crude oil storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry?
2, Was this crude oil storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015?
Yes
no
Source Req
Go to next I
Source Req
Source is nc
Storage Tar
Storage Tar
1111•1
1
.,.
Storage Tar
Go to the n
Go to the n
Go to the n
Go to the n
Go to the n
Source is sL
Continue-`
Storage Tar
3. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per year?
4. Does this crude oil storage vessel meet the definition of "storage vessel"' per 60.5430?
(Storage Tank is not subject to NSPS 00.00
Subpart A, General Provisions per §60.5425 Table 3
§60.5395 - Emissions Control Standards for VOC
§60.5413 - Testing and Procedures
§60.5395(g) - Notification, Reporting and Recordkeeping Requirements
§60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements
[Note: If a storage vessel is previously -determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2)
even if potential VOC emissions drop below 6 tons per year]
40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities
2. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria:
a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR
b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' (63.760(a)(3))?
1. js the tank located at a facility that is major' for HAPs?
3. Does the tank meet the definition of "storage vessel"4 in 63.761?
4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.761?
5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000?
'Storage Tank is not subject to MACT HH
Subpart A, General provisions per §63.764 (a) Table 2
§63.766- Emissions Control Standards
§63.773 - Monitoring
§63.774- Recordkeeping
§63.775- Reporting
RACT Review
RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements.
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may,"
"should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the
terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself.
YieS
"No
yes
Go to the n
The facility
Produced Water Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
'Facility AIRs ID:
Plan
Poin
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device '5,%-
Description:
Requested Overall VOC & HAP Control
Efficiency C:
Section 03- Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Produced Water Throughput =
Requested Permit Limit Throughput =
Potential to Emit (PTE) Produced Water
Throughput=
Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating =
Barrels (bbl) per year
Barrels (bbl) per year
Secondary Emissions - Combustion Device(s)
Heat content of waste gas= 3 ;� I;„Btu/scf
Volume of waste gas emitted per BBL of
liquids produced =« 'scf/bbl
Actual heat content of waste gas routed to combustion device =y
Requested heat content of waste gas routed to combustion device =
0 MMBTU per year
0 MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash. emissions?
Emission Factors Produced Water Tank
Pollutant
Uncontrolled Controlled
(lb/bbl) (lb/bbl)
(Produced
Water
Throughput)
(Produced Water
Throughput)
VOC
0.00
0.000
0.000
Benzene
Toluene
MENAMIEEM
n -Hexane
224 TMP
0.000
0.000
Control Device
Pollutant
Uncontrolled Uncontrolled
)Ib/MMBtu) (lb/bbl)
(Produced
Water
Throughput)
(waste heat
combusted)
Emission Factor Source
Emission Factor Source
PM10
PM2.5
0.0000
0.0000
0.0000
0.0000
NOx
CO
Section 05 - 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)
VOC
PM10
PM2.5
NOx
CO
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.9
0.0
0.0
0.0
0.0
0.0
0.0
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
'Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 IMP
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
Section 06 - Regulatory Summary Analysis
Regulation.3, Parts A, B
Not enoughinformation
Regulation 7, Section XVII.B, C1, C.3
Storage Tank is not subject to Regulation 7, Section XVII
Regulation 7, Section XVII.C.2
Storage Tank is not subject to Regulation 7, Section XVR.C.2
Regulation 6, Part A, NSPS Subpart 0000
Not enough information
(See regulatory applicabilityworksheet for detailed analysis)
11 of 33 . K:\PA\2017\ 17WE0964.CP1.xlsm
Produced Water Storage Tank(s) Emissions Inventory
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn
at the facility being permitted and analyzed using flash liberation analysis?This sample should be considered
representative which generally means site -specific and 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 maybe appropriate to
use an alder site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing.
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 09 - Inventory SCC Coding and Emissions Factors
AIRS Point#
0
Process# SCC Code
01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+Flashing losses
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM1D. #DIV/01 0 lb/1,000 gallons liquid throughput
PM2.5 #DIV/01 0 lb/1,000 gallons liquid throughput
NOx #DIV/0l 0 lb/1,000 gallons liquid throughput
VOC 0.0 0 lb/1,000 gallons liquid throughput
CO #DIV/01 0 lb/1,000 gallons liquid throughput
Benzene 0.00 0 lb/1,000 gallons liquid throughput
Toluene 0.00 0 lb/1,000 gallons liquid throughput
Ethylbenzene 0.00 0 lb/1,000 gallons Squid throughput
Xylene 0.00 0 lb/1,000 gallons liquid throughput
n -Hexane 0.00 0 lb/1,000 gallons liquid throughput
224 TMP 0.00 0 lb/1,000 gallons Squid throughput
12 of 33 K:\PA\2017\17WE0964.CP1.xism
Produced Water Storage Tank Regulatory Analysis Worksheet
Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb.
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
'You have indicated that source id in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3,Part B, Section II.D.1.M)
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 30 TPY (Regulation 3, Part B, Section 11.0.3)?
You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M)
3. Are total facility uncontrolled VOC emissions greater than 2 TPY, Max greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)?
'Not enough information
Colorado Regulation 7, Section XVII
1. Is this tank located at a transmission/storage facility?
2. Is this produced water storage tank'. located at an oil and gas exploration and production operation , well production facility2, natural gas compressor station or natural gas processing plant?
3. Is this produced water storage tank a fixed roof storage tank?
4. Are uncontrolled actual emisslons4of this storage tank equal to or greater than 6 tons per year VOC?
'Storage Tank Is not subject to Regulation 7, Section XVII
Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.C.1 - Emissions Control and Monitoring Provisions
Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply.
Yes
IStorage Tank is not subject to Regulation 7, Section XVII,C.2
Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry?
2. Was.thls produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015?
3. Are potential VOC emissions2 from the individual storage vessel greater than or equal to 6 tons per year?
4., Does this produced water storage vessel meet the definition of "storage vessel"1 per 60.5430?
Yes
' Not enough information
Subpart A, General Provisions per §50.5425 Table 3
§60.5395 - Emissions Control Standards for VOC
§60.5413 - Testing and Procedures
660.5395(g) - Notification, Reporting and Recordkeeping Requirements
§60.5416(c) - Cover and Closed Vent System Monitoring Requirements
§60.5417 - Control Device Monitoring Requirements .
[Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2)
e,ven if potential VOC emissions drop below 6 tons per year]
RACT Review
RACT review is required if Regulation 7 does not apply AND If the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements.
Disclaimer
Source is nc
Storage Tar
Continue -'
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its
' implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may,"
"should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the
terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself.
Glycol Dehydrator Emissions Inventory
Section 01- Administrative Information
LacilityAlts 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
Reboiler Bumer
Stripping Gas
Dehydrator Equipment Description
Coun
Plant Point
Mscf/day
gallons/minute
One (Y) natural gas dehydration unit (Make:, Model: , Serial Number. ( with a design capacity of MMscf per day. This
enitisions unit is equipped with (Make: , Model:) driven glycol pump with a design capacity of gallons per minute. This
dehydration unit is equipped with a still vent.
Emission Control Device Description: Emissions from the still vent are routed to the. As a secondary control device, still vent emissions are routed to the
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions- Dehydrator Still Vent and Flash Tank (H -present)
Requested Permit Limit Throughput= S'`�'u"IyIy3;MMscf per year
lff:E.4aa a
Potential to Emit (PTE) Throughput = 0 MMscf per year
Secondary Emissions- Combustion Device(s) far Air Pollution Control
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:
.i.`: Control Efficiency %
Wet Gas Processed:
Still Vent Primary Control: 0.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 0.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Wet Gas Processed:
Flash Tank. Primary Control: 0.0 MMscf/yr
Flash Tank Secondary Control: • 0.0 MMscf/yr
Wade Gas Combusted:
Flash Tank Primary Control: 0.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Glycol -Dehydrator Emissions Inventory
Section OS- Emissions Inventory
Did operator requesta buffer?
Requested Buffer (%),
Section 04- Emissions Factors & Methodologies
Input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled. (lb/hr)
VOC
0
0
Benzene
'i �,3a;_
0
0
Toluene
% l;Ij1
0
0
Ethylbenzene
. i% 3%
0
0
Xylenes
"' ?
0
0
n -Hexane
0
0
224 -IMP
i...'?-".. i:.'iN,r9rriiiirigri
0
0
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled(Ib/Lr)
Controlled (lb/hr)
VOC -
133 3.:?�;:r a:=�
0
0
Benzene
' g!{„
0
0
Toluene
0
0
Ethylbenzene
�.,.'"',-,","F„llnUAs?
0
0
Xylenes
viz
0
0
n -Hexane
F;r^,,; .:)
0
0
224TMP
lsll ,y, °'
0
D
Emission Factors
Ethylbenzene
Xylene
Pollutant
VOC
Benzene
Toluene
Glycol Dehydrator
Uncontrolled Controlled
(Ib/MMscH) (Ib/MMsct)
(Wet Gas
Throughput) (Wet Gas Throughput)
0010/01 NDW/Ol
4010/01 NDIV/OI
NDIV/Ot BDIV/01
0O1O/01
NDIV/ol
NDIV/Ot
NDIV/01
Still Vent Primary Control Device
NOW/O1
0010/01
ND W/OI
NDW/01
n -Hexane
224 IMP
Emission Factor Source
PolluteM
Pollutant
PM2.5
NOx
CO
Pollutant
PM10
PM2.5
NOx
CO
PM10
PM2.5
Uncontrolled
(Ib/MM eta)
(Waste Heat
Combusted)
Uncontrolled
(Ib/MMscf)
(Waste Gas
Combusted)
0.0000
0.0000
a.aoca
0.0000
Still Vent Secondary Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu) (Ib/MMscf)
(Waste Heat (Waste Gas
Combusted) Combusted)
MOW N.MrVrrrriirMrr 0.0000
0.0000
Flesh Tank Primary Control Device
Uncontrolled Uncontrolled
(Ib/MMetu) (Ib/MMscf)
(Waste Fleet (Waste Gas
Combusted) Combusted)
d lflh 1sf'S 0.0000
..,1.. 0.0000
0.0000
Flash Tank Secondary Control Device '
Uncontrolled •
(Ib/MMBtu)
(Waste Heel
Combusted)
Uncontrolled
(Ib/MMsci)
(Waste Gas
Combusted)
0.0000
0.0000
0.0000
0.0000'
Emission Factor Source
Emission Factor Source
Emission Factor source
Emission Factor Source
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
. (tons/year) (tans/year)
Requested Permit Limits
Uncontrolled Controlled .
(tons/year) (tons/year)
PM10
0.0
- 0.0
0.0
0.0
0.0
PM2.5
0.0
0.0
0.0
0.0
0.9
Not
0.0
9.0
0.0
0.0
0.0
CO
0.0
0.0
0.0
0.0
0.0
VOC
0.0
0.0
0.0
0.0
0.0
Potential to Emit
Actual Emissions
Requested Permit Limits
Hazardous Air Pollutants
- Uncontrolled
Uncontrolled Controlled
Uncontrolled Controlled
(lbs/year)
(lbs/year) (lbs/year)
(lbs/year) (lbs/year)
Benzene
0
0
0
0
0
Toluene
0
0
0
0
0
Ethylbenzene
0
0
0
0
0
Xylene
0
0
0
0
0
n-Hetane
0
0
0 -
0
0
224TMP
0
0
0
0
0
M1
Glycol Dehydrator Emissions Inventory
Section 06- ReeuletorySummary Analysts
Regulation 9, Parts A, 8
Regulation 7, Section 0511.8,0
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MACTSubpart HH (Area)
Regulation8, Part E, MACT Subpart HH (Major)
Regulation 8, Part E, MACT Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Not enough Information
Dehydrator is not subject to Regulation 7, Section 0511.8, 03
The control device for this dehydrator is not subjectto Regulation 7, Section XVII.B.
Dehydrator is not subject to Regulation 7, Section X0.11
You have indicated that this facility is not subiactto Area Source requirements of M
You have indicated that this facility is not subject to Major Source requirements of f
Not enough information
Section 07- Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the Glycaic 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 limi
Does the company request a control device efficiency greater than 95% fora flare or combustion device?
ti yes, the permit will contain and Wale) compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section OS- Inventory SCC Coding and Emissions Factors
AIRS Point It
0
Process #
01
5CC Code
Uncontrolled
Pollutant Emissions Factor Control % Units
PM10 #015/0 0.0% b/MMscf
PM2.5 #0111/0 0.0% b/MMscf
NOM #015/0 0.0% b/MMscf
VOC #015/0 #015/01 b/MMscf
CO #015/0 0.0% b/MMscf
Benzene #0111/0 #01V/01 b/MMscf
Toluene #015/0 #015/01 b/MMscf
Ethylbenzerre #015/0 #015/01 b/MMscf
Xylene #015/0 #015/01 b/MMscf
n -Hexane #015/0 #015/01 b/MMscf
224 TMP #0111/0 #0111/01 b/MMscf
Dehydrator
Colorado Regul
ATTAINMENT
1. Are uncont
2. Are total fa
NON -ATTAIN M
1. Are uncont
2. Are total fa
Colorado Regul
1. Is this glyco
2. Is this glyco
3. Is the sum
4. Are actual t
Section XII.
MACT Anal\
1. Is the dehyi
a.
b.
2. Is the dehyi
40 CFR, Part 63
Area Sourci
1. Is the dehyi
Exemption:
2a.
2b.
3. Is the unit I
Major Sour
1. Does the fa
Small or La
2a.
2b.
Small Dehv
3.
4.
40 CFR, Part 63
1 Is the facilit
Small or La
2a.
2b.
Small Dehv
3.
4.
Colorado Regul
1. Is the dehyi
2. Is this dehy
3. Is this deh'
4. Was this gl)
4a.
5. If construct
Section XVI
Section XVI
Alternative
6.
Regulatory Analysis Worksheet
ation 3 Parts A and B - APEN and Permit Requirements
You have indicated that source is in the Non -Attainment Area
rolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Pa
cility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TF
You have indicated that source is in the Non -Attainment Area
ENT
rolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, S
cility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater thi
Not enough information
ation 7, Section XII.H
it natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/r
it natural gas dehydrator located at an oil and gas exploration and production operation'', natural gas compressor
of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary
uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Re
IDehydrator is not subject to Regulation 7, Section XILH
,H — Emission Reductions from glycol natural gas dehydrators
rsis
drator located at an oil and natural gas production facility that meets either of the following criteria:
A facility that processes, upgrades or stores hydrocarbon liquids'' (63.760(a)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural
gas transmission and storage source category or is delivered to a final end user2 (63.760(a)(3))?
drator located at a facility that is a major source for HAPs?
Not enough information
, Subpart MACT HH, Oil and Gas Production Facilities
e Requirements
drator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))?
s
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per d
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
ocated inside of a UA plus offset and UC boundary area?
You have indicated that this facility is not subject to Area Source requirements of MACT HH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 Emissions Control Standards
§63.773 - Monitoring Standards
§63.774 - Recordkeeping
§63.775 - Reporting
•ce Requirements
icility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-
rge Dehy Determination
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per d
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
Requirements
Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B)
For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation;
IYou have indicated that this facility is not subject to Major Source requirements of MACT HH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards
§63.773 - Monitoring
§63.774 - Recordkeeping
§63.775 - Reporting
, Subpart MACT HHH, Natural Gas Transmission and Storage Facilities
:y wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the
rge Dehy Determination
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per d
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
Requirements
Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and
For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicabl
Not enough information
Subpart A, General provisions per §63.1274 (a) Table 2
§63.1275 - Emissions Control Standards
§63.1281 -Control Equipment Standards
§63.1283 - Inspection and Monitoring
§63.1284 - Recordkeeping
§63.1285 - Reporting
ation 7, Section XVII.D
drator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)?
drator located at a transmission/storage facility?
ydrator located at an oil and gas exploration and production operation , natural gas compressor station
ycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)?
equal to or greater than 6 tons per year VOC or 2 tpy VOC if the dehydrator is located within 1,320 feet of a
building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)?
.ed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to
Dehydrator is not subject to Regulation 7, Section XVII.B, D.3
II.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
II.D.3 - Emissions Reduction Provisions
Emissions Control (Optional Section)
Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary
The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e
Section XVII.B.2.e - Alternative emissions control equipment
Disclaimer
Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not
a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the
individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any
conflict between the language of this document and the language of the Clean Air Act„ its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute
or regulation will control. The use of non -mandatory language such as "recommend," "may," "should,"
and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology
No
Continue - You have indicated the attainment status on the Project Summary Sheet.
Source is not subject - You have indicated the facility type on the Project Summary Sheet.
Continue - Source may be subject to MACT HHH. You have indicated the source category on the Proj
Source is not subject - You have previously indicated this in the beginning of the MACT section
Source is not subject - You have previously indicated this in the Reg 7, Section XII determination
ject Summary Sheet.
Hydrocarbon Loadout Emissions Inventory
Section 01 -Administrative Information
�Fadlity AIRS ID:
County
Plant Point
Section 02- Equipment Desedption Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Is this loadeut controlled?
Collection Efficiency.
Control Efficiency:
0.00
Requested Overall VOC & HAP Control Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Hydrocarbon Loadout
Actual Volume Loaded=
Requested Permit Limit Throughput=
Potential to Emit (FTE) Volume Loaded=
Barrek (bbl) peryear
Barmy ?bbl) per year
Barrels (bbl) per year
Secondary Emissions-CombustionDev!ce(s)
Heat content of waste gas= ,- Btu/scf
Volume of waste gas emitted per year= if010/01 scf/year
Actual heat content of waste gas routedto combustion device=
Requested heat content of waste gas routed to combustion deice =
Potential to Emit (PTE) heat contentaf waste gas routed to comburtion device =
Section 04- Emissions Factors & Methodologies
Does the company use the state default emissions factors to estimate emissions?
Does the hydrocarbon liquid Ioadingopeation utilize submerged fill?
Are Me emissions factors based on astabilized hydrocarbon liquid sample drawn atthe facility
being permitted?
Loading Lass Equation
L=12.46" SsPeM/T
Actual Volume Loaded While Emissions Controls Operating=
4DIV/0l MMRTU per year
0DIV/01 MMRTU per year
MVP! MMBTU per year
Factor
Meaning
Value
Units
Source
s
Saturation Factor
o.s
1/li0,
P
True Vapor Pressure
M
Molecular Weight of Vapors
� ;,r y/3, lit:.
lb/Ib-mol
I
1
T
Liquid Temperature
,°x:1 ,. +Rankine
''
-
'
L
LoadingLosses
4010/01
lb/1000 gallons
_ .
x ,...
_.._
,.,,,d-
---.3, ,,. ..
0010/0! Ib/bH
Component
Mass Fraction
Emission Factor
Units
Sours
Benzene
01 ITik, T331EI i 3 L'L ::
0DIV/0!
Ib/bbl
'
�l
3 (i
'r'
-
:. :
Toluene
Di,Di,.4O /n,,fly'1,1 °' •
0D10/0)
lb/bbl
.�.,.9
, rY ..
Ethylbenze
:, ,0,L_a.:, n.,.,
001st/0!
lb/bbl
<
:-al ,_
3 - : M
Sti:t , . ..,,,g 1 1:,n:
Xylem?
3 3
0010/0!
lb/bbl
i
o
3
3
'
n-Hemne
P
4DIV/0!
lb/bbl
224 'IMP
.....i ,,.0...: k:`i
4010/01
lb/bbl
fi„,,, ;_
- fuSi
Iliir,$I,,;:
,., „a,eil ?f 111/ai11i)kiilgls„j,
,•,'a
Pollutant
IESEEIMM
Pollutant
Hydrocarbon Laadou5
Uncontrolled
Controlled
(11s/bbl)
)lb/bbl)
(velum
Loaded)
0.00+00
0.00E+00
0,00E+00
0.00E+00
0.00E+00
0.00E+00
0.00E+00
(Volume Loaded)
0.00E+00
0.00E+00
0.00E+00
0.00E+00
0.00E+00
0.00E+00
0.00E+00
Control Device
Uncontrolled
(Ib/MMesu)
uncontrolled
Ob/bbl)
Wolume
Loaded)
(waste heat combusted)
__ 14iilI
t m
®'
00
Emission Factor Source
Emission Factor Source
Section 05- Emissions Inventory
Criteria Pollutants
Potentialto Emit
Uncontrolled
ltore/year)
Actual Emissions
Uncontrolled Controlled
Rom/year) (tam/yeer)
Requested Permit Unit
Uncontrolled Controlled
Itom/tearl (mre/Xarl
PM10
0010/01
401V/01
0010/01
1DIV/01
O010/01
PM2.S
0010/01
0010/0!
0010/0!
0010/0!
0010/0!
SO5
0010/01
#010/0!
gD11//01
IIDIV/0!
0DIV/O1
HOx
0010/01
4DIV/01
1010/01
401V/0!
0010/01
VOC
0.00
0.00
0.00
0.00
0.00
CO
0010/01
8010/0!
0010/01
BDIV/07
0DIV/00
Potential to Emit
Actual Emissions
Requested Permit Limits
Hazardous Alr Pollutants
Uncontrolled
Uncontrolled Controlled
Uncontrolled Controlled
(lbs/year)
leo/year) Ilbs/yearl
llbs/year? (Ibs/}war)
Benzene
D
0
0 _
0
0
Toluene
0
0
0
0
0
Ezhylbenzerre
0
0
0
0
0
Xylene
0
0
0
D
D
Hex n-ane
0
0
0
0
0
224IMP
0
0
0
0
0
31 of 33 K:\PA\2017\S7WE0964.CPLzbm
Hydrocarbon Loadout Emissions Inventory
Section 06 -Regulatory summary Analysis
Regulation 3, Parts A, B
PACT- Regulation 3, Part B, Section 111.0.2,a
(See regulatory applicability worksheet for detailed analysis)
Section 07 -Initial and Periodic Sampling and Tasting Requirements
Not enough information
Not enough information
Does the company request a control device efficiency greaterthan 95%far a Hereof combustion device?
If yes, the pemirt will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section 09-IeventorySCC Coding and Emissions Factors
AIRS Pointe
Process If 5CC Code
01 4-03.001.32 Crude Oil: Submerged Loading Normal Service 15-0.01
-B
Uncontrolled
Emissions
Pollutant Factor Control% Units
PM10 A0IV/cal b/1,000 gallons transferred
PM2.5 00IV/01 6/1,000 gallons transferred
500 0DIV/0! b/1,0D0gallons transferred
000 0ulV/01 b/1,000 gallons transferred
V0C 0.0 b/1,000 gallons transferred
CO 1550/01 b/1,000gallons transferred
Bentene 0.00 6/1,000 gallons transferred
Toluene 0.00 b/1,000 gallons transferred
Ethylbentene 0.00 6/1,000 gallons transferred
Xylene 0.00 b/1,00ugallons transferred
n -Hexane 0.00 b/1,000 gallons transferred
224TMP 0,00 b/1,000 gallons transferred
32 of 33 KAP/M.2017 17WC0964.CP1xlsm
Hydrocarbon Loadout Regulatory Analysis Worksheet
Colored° Regulation 3 Parts q end B-APEN end Permit Requirements
1001kazx b,diceted that "roues Is i„tile 2easntt0 1mentaseo
0 ?M ME -
1, Am
isec rolled actual emissions from any criteria pollutants from this individual source greater than 3, Part A, Section11.0.1.67?
2. Is thelwdot located sten esoratlon and production sae le.,Well pad( (Regulation 3, Part R, Section maw
It le loot..[ operation loading less awn 10,000 gallons pm BEILs) of crudeoil nerd, on en annual average basis? •
Is the loadout operation loading less than 6,]5o bbls per Veered cdgensate tda splash AIR
5, Iz Ne loadouf operation loading less than 16,300 bhls nerves,' of condensate via subreel354 fill procedure?
6. Pre (mat fadllty uncontrolled VOC emissions greater Man 5 Mb 200 greater than 10TH or CO ((missions greater than 10 TPV(Regulsats 3, Par( Es, Section 11.0,31?
heva Indian°[ tit, secrets,. the 10001101,01010005
rtINM6
I. Are M
I. Are uncontrolled emissions from any criteria pollutants from Nis Individual source greater than l TN (Regulation 3, PartA, Section 110..102
2. Is the loadout located eta," esploratloo and production site (e.g., well pad) (Reguladon 3, Part ti, Section II.0.1.0?
151gsp26 loadout',per.. loading less 613010,000 gallons(23BMks)?000 of crude oil nerday m sneer,. average basis?
4. 5 the loadout operation loading less than 6,150 bbls per yeanof condensate via spleait fill?
5. Is the lout operation loading less than 16,306 bids gammas of condensate vla submerged All procedure?
6. Are total facility uncontrolled 00C emissions horn Me greater than 21W, NOP greater than 5 TPV or CO emissions greater tban5 TPY(Regulation 3, Part 6,Sectlonll.0.1)?
1110 mem up inter seams.
r. MR- Are uncontrdled VOC emissions horn thelosdopt operation greater than 20tpy(Regulation 3, Part 6, Section lll.D.2.al?
1110 ouaug:: in:armx:
Disclaimer
This rkeurrentesslsts operators with cbtermining appfcablflydcertain requirements el the Clean Air Act, is Implementing regulations, 50440 Quality Contra Commission mutilations. This 0xumanl is not a
rule o -reviles, and the analysis a -contains may not apply to particular situation based upon the it lviduel tads end circumstances. This skcumantdvs not charge or substitute los anylaw, regulation, ce
anyotlzerlegaly binding requirement and is not legally enforce3b0 laths avant of any eon/ Get between the language oftl0s document endiha language dtse Clean AlrAct„ its Implementingr55ulatiaw,
and Air Quality Contest Commission regulations, the language oft the statute or tegulallo, will co trd. The use ofnommardatoy language such as "necmmeM,""may,""shoobt and "can," is intended to
463002. APCD Intenpratations and recommendations, Mandebry terminology such as "must" and "required' ate Intended 10 describe conlmiing requllernents under the tarms at the Clean AirAcl end Air
Quality Corlmlconmisslon regulations, but this document does not establish legslybir dig 1aguimments in and of itself.
Crude Oil Storage Tank(s) APEN -
Form APCD-210
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 tanks that store crude oil associated with oil and gas industry operations. If your emission
source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate
storage tanks, produced water storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/pacific/cdphe/air-permits.
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: /7 WE (257 L/ AIRS ID Number: 123 /gF5D / DO
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Discovery DJ Services LLC
Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Site Location
County: Weld
NAICS or SIC Code: 493190
Permit Contact:
Phone Number:
Manya Miller
(214) 414-1980
E -Mail Address2: manya@discoverymidstream.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 APCD via e-mail to the address provided.
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
368435
1I AYCOLORADO
I noamoilwtamieu
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit #t and AIRS ID]
Section 2 - Requested Action
• NEW permit OR newly -reported emission source
0 Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
▪ APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 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:
100,000
250,090 BBL EFR Stabilized Crude Oil Storage Tank
For existing sources, operation began on: aS
For new or reconstructed sources, the projected start-up date is: July 2018
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week 52
weeks/year
❑ Exploration Et Production (EEtP) site ✓❑ Midstream or Downstream (non EEtP) site
Will this equipment be operated in any NAAQS nonattainment area?
O
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
•
Yes
U
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•,
0
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualEl
emissions ≥ 6 ton/yr (per storage tank)? -
Yes
No
•
Form APCD 210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 2 I
Has.. l.moreeesni
COLORADO
Permit Number:
AIRS ID Number:
El Upward
❑ Horizontal
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
etuaLAnnual.Arnount
(6bliyear)
RequestedAnrn aLPermit:=L_imrt4
(bb1Lyear)
de Oil.ThroughPut :.
29,200,000
From what year is the actual annual amount?
Average API gravity of sales oil: 42.6 degrees
❑ Internal floating roof
Tank design: ❑ Fixed roof
RVP of sales oil: 7.0
2 External floating roof
Storage
TanklD
#�of Liquid Malifold Storage
Vessels in Storage Tank
Total Volu i f
-
" Storage Tank
(bbf) __:_
Installation Date=of Most
R��'e_cent Storage Vessehn
Date of First
Production -
(month/year)
Storage-Tank.(month/year)
Tx-ioi
1
100,000
NA
NA
Wells S&--viced•b this=Story di ank:oe Tank:Batte - EFtP:Sites On
.zr,,, AP1 N umber _
Name of 1Ne1L �.., .7,_ -
_:Newly Reported: Well a
ID
CI
- -
❑
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
5 The EEP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
eographica[ Coordinates
(Latrtude/Longrtude or UTM)
40.1915 N, -104.6109W
O eratof Stack '
P
lD No -
°Di§Char a Hei ht Above:"
4. g
-Ground Level i(feet) =-
--Tem -
PY
__,-,,,,M)_•.4„,-----_,
Flow Rate .``
_(ACFM) ; -
Velocity-
_
:., (ft/sec) _ -
N/A
Indicate the direction of the stack outlet:•(check one)
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Square/rectangle
❑ Other (describe):
Interior stack diameter (inches):
Interior stack width (inches):
❑ Upward with obstructing raincap
Interior stack depth (inches):
Form APCD-210 Crude Oil Storage Tank(s) APEN - Revision 02/2017
COLORADO.
Dm
Heeepb FntaeeMS
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
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.
Pollutants Controlled:
Vapor
❑ Recovery
Unit (VRU):
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
❑
Combustion
Device:
Pollutants Controlled:
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature:
MMBtu/hr
Make/Model:
Waste Gas Heat Content:
Btu/scf
' Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Describe the separation process, between the well and the storage tanks:
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 4
COLORADO
ayv®m Wftsbuc
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions 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 overall
(
Benzene
71432
6.15E-04 Of
Pot Otarlt
Descrrption`of Control Methods) -
Overall Requested Control
= Efficiency
- (%re ctior in em`issians) __
_,.,__-1 w . - -
VOC
NOx
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
riteria_Pollutant EmissionSinventory.
Actual Annual Emissions'
Jncontrolled ".
Emissions
(Tons/.,year)
Uncontr llec
Emissions
(Ton`sGyear)
tl- 0.
VOC
Ib/BBL
EPA Tanks
IZ,8 8,083-
NOx
CO
Non -Criteria'
eportable Pollutant Emissions=nventory,_
mission Eacto
• Uncontrolled
Basis
-Units
ctua
E&P and EPA Tanks
38
nnuaL',Emissions _
ontrolled
missions
'oundsf year)
9.02E-07
lb/BBL
38
Toluene
108883
5.86E-07
lb/BBL
E&P and EPA Tanks
Zc
zs
Ethylbenzene
100414
7.85E-08
Ib/BBL
E&P and EPA Tanks
3
Xylene
1330207
6.68E-08
ib/BBL
E&P and EPA Tanks
3
n -Hexane
110543
6.30E-06 f
Ib/BBL
E&P and EPA Tanks
Z41
2(Q l
2,2,4-
Trimethylpentane
540841
5.73E-07
Ib/BBL
E&P and EPA Tanks
2`1
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.
7 Annual emissions fees will be based on actual controlled emissions reported. If source has -not yet started operating, leave blank.
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
�Voo..
5 1 aRo.ne��m�
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 informationsubmitted with this application is complete, true
and correct. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature of l> gaily Aut'zed Person (not a vendor or consultant)
Cory G. Jordan
Date
EVP Operations
Name (print)
Title
Check the appropriate box to request a copy of the:
Er 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 $152.90 and the General Permit
registration fee of $250, if applicable, to:
Colorado Department of Public'Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
For more information or assistance call:
Small Business Assistance Program
. (303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
Crude Oil Storage Tank(s) APEN
Form APCD-210
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 maybe 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 tanks that store crude oil associated with oil and gas industry operations. If your emission
source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate
storage tanks, produced water storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/pacific/cdphe/air-permits.
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:
I7tiV M 65C
AIRS ID Number: /23 /gFgo / a 02 -
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Namei:
Site Name:
Discovery DJ Services LLC
Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Site Location
County: Weld
NAICS or SIC Code: 493190
Permit Contact:
Phone Number:
Manya Miller
(214) 414-1980
E -Mail Ad dress2: manya@discoverymidstream.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 APCD via e-mail to the address provided.
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 1 I
368436
Co
(COLORADO
µn y a
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
r❑ NEW permit OR newly -reported emission source
✓❑ Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
-OR -
°
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment
❑ Change permit limit
❑ Change company name
❑ Transfer of ownership3
OR -
• APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit exempt/grandfathered source
•
Additional Info it Notes:
❑ Other (describe below)
3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information Ioo,000
250,000 BBL EFR Stabilized Crude Oil Storage Tank
General description of equipment and purpose:
For existing sources, operation began on: 3S
�S�ld
1-
For new or reconstructed sources, the projected sta -u ate is: July 2018
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day
7
days/week
52
weeks/year
❑ Exploration a Production (E&P) site ✓❑ Midstream or Downstream (non E&P) site
Will this equipment be operated in any NAAQS nonattainment area?
0
Yes
•
No -
Are Flash Emissions anticipated from these storage tanks?
•
Yes
•
No
Are these storage tanks subject to Colorado Oil and_Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•
O
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualel
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
■
Form APCD-210 - Crude Oit Storage_Tank(s) APEN - Revision 02/2017
LTCOLORADO at
NW. 2 327 ° bhWvwnd
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
ActualAnnual Amount
(bb(l year) --
Re guested�AnnuaL-Permit=Limrt4 :
(bbl/year)
Crude OilThroughput
29,200,000
From what year is the actual annual amount?
Average API gravity of sales oil: 42.6 degrees
O Internal floating roof
Tank design: ❑ Fixed roof
RVP of sales oil: 7.0
E External floating roof
Storage ,
Tank 1D
-_.
#;of Liquid Marnfold Storage
Vessels to Storage Tank .
un
TotaLVolume of
Storage_Tank
._ J_(bb0_
InstallatYon Dateof Most
Recent'Storage Vessel in
Date ofFirst
Production , -
(month/year), _
Storage Tank_.(month/year)_.
TR-102
1
100,000
NA
NA
'I- NUmbe
Wells Serviced b this Stora e_Tank or Tank Batte 5 EaP Sites On ;
-_ dell „_ __._ Newly: Reported Well`:
Name of _W
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
5 The EEP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geographual-Coordinates
(Latitude/Longitude or UTM)
40.1920 N, -104.6111W
Operator Stack
-_1D No.
•:Discharge Height Above
Grouod-.Level-feet) . __
'Temp.
(°F) —
Flow Rate ' _
_` (ACFM) =r
Velocity,
--'(ft/see)
.
N/A
Indicate the direction of the stack outlet: (check one)
❑ Upward ❑ Downward
❑ Horizontal
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches):
Interior stack width (inches): Interior stack depth (inches):
Form APCD-21O - Crude Oil Storage Tank(s) APEN - Revision 02/2017
3IAY
COLORADO
uer+,®��rtiweu�
IWIbb prvY,mueaM
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Control Device Information
E Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section,
Pollutants Controlled:
Vapor
❑ Recovery
Unit (VRU):
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed (emissions vented):
Make/Model:
❑ Combustion
Device:
Pollutants Controlled:
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature:
MMBtu/hr
Make/Model:
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
%
Section 7 -Gas/Liquids Separation Technology Information (EItP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Describe the separation process between the well and the storage tanks:
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 4 I
COLORADO
tq.rrahostm wmc
/Math 6 ETnmevnd
Permit Number:
AIRS ID Number:
9.02E-07
[Leave blank unless APCD has already assigned a permit # and AIRS ID] .
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form6.
If multiple emission control methods were identified in Section 6, the following table can be used to state the overall
Pollutant
Description -'of Control Metfod(s)''
_ - _. -
Overall Requested Control
= iency,
Effic
-- (%:?eduction in emissions) _
VOC
NOx
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
Criteria Pollutant Ediissions_Inventory
EPA Tanks
11,$ 8.083
UnconCrotled
Emissions
Ronsl year,I . ;
Controlled
Emissions?
(Tonslyear).
ont?;i1 d';
Emissions
(ron Dear,)
VOC
6.15E-04
Ib/BBL
NOx
CO
on_Gntna_Reportable QolLutant Emissions_Invento
mission Factor°
ctual Annual Emissions
i,7nits
E&P and EPA Tanks
U ncontrolledf
Emissions
.(Pounds/ y_ear)
ControRe
Emissions'
Pounds/year)
Benzene
71432
Ib/BBL
3$
Toluene
108883
5.86E-07
Ib/BBL
E&P and EPA Tanks
2S
ZS
Ethylbenzene
100414
7.85E-08
Ib/BBL
E&P and EPA Tanks
Xylene
1330207
6.68 E-08
Ib/BBL
E&P and EPA Tanks
3
n -Hexane
2,2,4-
Trimethylpentane
110543
540841
6.30E-06
5/3E-07
Ib/BBL
Ib/BBL
E&P and EPA Tanks
E&P and EPA Tanks
Z(pi
2`A
3
2-41
z4
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesi ; site specific
emissions factors according to the guidance in PS Memo 14-03.
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, Leave blank.
KPi
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
5 �COLORADO
-
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. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature ofegally Au t f'orized Person (not a vendor or consultant)
Cory G. Jordan
Date
EVP Operations
Name (print)
Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
2 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 $152.90 and the General Permit
registrationrfee of $250, if applicable, to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD=210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 6 I
co
Dquromra at Pali.
COLORADO
Xe. F. Oe.mmN
Crude Oil Storage Tank(s) APEN -
Form APCD-210
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 tanks that store crude oil associated with oil and gas industry operations. If your emission
source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate
storage tanks, produced water storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/pacific/cdphe/air-permits.
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:
/47WE: O9 6(1. AIRS ID Number: /73 /yF5D/ 003
[Leave blank unless APCD has already assigned a permit M and AIRS ID]
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address:
(include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Site Location
County: Weld
NAICS or SIC Code: 493190
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address2: manya@discoverymidstream.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 APCD via e-mail to the address provided.
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
368437
1II
COLORADO
FFwl�b Eritlrw4wN
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
✓❑ Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
-OR-
❑ - MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 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:
For existing sources, operation began on:
100,000 BBL EFR Stabilized Crude Oil Storage Tank
For new or reconstructed sources, the projected start-up date is: July 2018
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week
❑ Exploration E Production (EEP) site
52
weeks /year
❑✓ Midstream or Downstream (non EEtP) site
Will this equipment be operated in any NAAQS nonattainment area?
151
Yes
•
No
Are Flash Emissions anticipated from these storage tanks?
•
Yes
IS
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)•
805 series rules? If so, submit Form APCD-105.
Yes
No
®
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
O
■
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
COLORADO
2I °`""®°°`of'ab.
%alb EMYmuene
Permit Number:
AIRS ID Number: /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
ActualAnnualArnount
• (bbi/year)
eguest_ed Annual-PermitLimit4
(bbl/year) , J
Crude Oil Throughput _
29,200,000
From what year is the actual annual amount?
Average API gravity of sates oil: 42.6 degrees
❑ Internal floating roof
Tank design: ❑ Fixed roof
RVP of sales oil: 7.0
❑✓ External floating roof
Storage
Tank �D
#of Liquid Mantfbld Storage °
= Vessels in Storage Tank
: Total Volume of
Storage Tank':
-(bbl) -_'_'
Installation Date of Most
Recent Storage Vessel in
Storage Tank (month/year_-)
Date of First
Production
(month/year) _?
Tk-103
1
100,000
NA
NA
_ Wells Se vied by this:Storage_Tank or Tank Battery5 (EEaP S{t Oni ) -
;API Number _
_ Name of Well `_-
Newly -Reported Well:_
- -
❑
_
❑
_
❑
4 Requested values wilt become permit limitations. Requested limit(s) should consider future growth.
5 The EEEP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geographical _Coordinates
(Latitude/Longitude or'CLTM)
40.1920 N, -104.6106W
Operator Stack
-1D No _ _- —
Discharge Height Above :
Temp.
--_,(°F) _-
Flow Rate :
— _ (ACFM) _
Velocity
__- -(ft/sec) -_
N/A
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches):
Interior stack width (inches): interior stack depth (inches):
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Control Device Information
E Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
❑ Recovery
Unit (VRU):
Pollutants Controlled:
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed (emissions vented):
Make/Model:
❑ Combustion
Device:
Pollutants Controlled:
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature:
MMBtu/hr
h r
Make/Model:
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
Section 7 -Gas/Liquids Separation Technology Information (EEtP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Descnbe the separation process between the well and the storage tanks:
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
.AyI COLORADO
A •
& Eerrunnamml
!;I
Benzene
71432
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form6.
If multiple emission control methods were identified in Section 6, the following table can be used to state the overall
(or combined) control efficiency (% reduction):
VOC
NOx
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
VOC
6.15E-04
lb/BBL
Criteria Pollutant EmissionsLnventory
EPA Tanks
controlled
Emissions
(Tons/yearq
ontroRed
missions
(Tonsf_<year)
uested. nnualPerrni
Emission'Limit(s)4
Uncontf dR
Emissions : _
(Tonsyear)
12,E 8-ge3-
1Mj 8.983
NOx
CO
Non Cntena`1Re,'portable Pollutant Er nssions inventory.._:
mission Facto
Uncontrolled_
• iBasis .
lb/BBL
ource ''
(AP 42,
Mfg etc)
ctual Annual Em1SSlOnsV
-Uncontrolled;
Emissions
(Pounds/year.`)
38
9.02E-07
E&P and EPA Tanks
30
Toluene
1O8883
5_.86E-07
Ib/BBL
E&P and EPA Tanks
25�
Z 5
Ethylbenzene
Xylene
100414
7.85E-08
Ib/BBL
E&P and EPA Tanks
3
-s
1330207
6.68 E-08
Ib/BBL
E&P and EPA Tanks
3
n -Hexane
2,2,4-
Trimethylpentane
11O543
54O841
6.30E-06
5.73E-07
Ib/BBL
Ib/BBL
E&P and EPA Tanks
E&P and EPA Tanks
2-4-1
2L
2c.
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.-
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
iii
l li 13)1q -
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
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. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature egally e horized Person (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
Name (print)
Title
Check the appropriate box to request a copy of the:
❑ 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 $152.90 and the General Permit For more information or assistance call:
registration fee of $250, if applicable, to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
Crude Oil Storage Tank(s) APEN -
Form APCD-210
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 tanks that store crude oil associated with oil and gas industry operations. If your emission
source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate
storage tanks, produced water storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/pacific/cdphe/air-permits.
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: f 7 WE 0 (44- AIRS ID Number: 173 /9r51)1 DD
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address:
(Include Zip code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Site Location
County: Weld
NAICS or SIC Code: 493190
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address2: manya@discoverymidstream.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 APCD via e-mail to the address provided.
Form APCD-210 - Crude•Oil Storage Tank(s) APEN - Revision 02/2017
368438
COLORADO
11 b
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit it and AIRS ID)
Section 2 - Requested Action
❑ NEW permit OR newly -reported emission source
Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
- OR -
• MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
OR -
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 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:
For existing sources, operation began on:
100,000 BBL EFR Stabilized Crude Oil Storage Tank
For new or reconstructed sources, the projected start-up date is: July 2018
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week 52
weeks/year
❑ Exploration E Production (EftP) site ❑✓ Midstream or Downstream (non EftP) site
Will this equipment be operated in any NAAQS nonattainment area?
p
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
■
Yes
IS
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•
p
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
O
II
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
AltCOLORADO
HMI.b ETwawotl
1
❑ Upward
❑ Horizontal
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
Ac teal Annual Amount
(bbi/ year) '
Requested_Annuaf_Permit Limit -:
(bb!/ year)
29,200,000
Crude OiLThroughput __
From what year is the actual annual amount?
Average API gravity of sales oil: 42.6
Tank design:
❑ Fixed roof
degrees
❑ Internal floating roof
RVP of sales oil: 7.0
❑✓ External floating roof
Storage
Tank ID
of Liquid Manifold Storage
Vessels in Storage Tank -
Total Volume o_f.
Storage_Tank<
Installation Date`of Most
Recent Storage Vessel in
Storage Tank month/year)
Date of_F.irst
Production _
(monthlytar)
Tk-201
258,000
NA
NA
100,000
143 f✓ PS , I
/I4114 —
Number.
Welts Sernced:by this_ Storage`Tankor Tank"Battery5 (EftP,Sites Only)
-NewlyReported Well__
ame of_Well
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
5 The EEP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geog aphfcal`Coordjnates
(Latitude/Longitude. orUTM)
40.1930 N, -104.6108 W
Operator Stack
ID.No.
Discharg a Height Above'-
_ Ground LeyeL(fee0 =
-
Temp:.
(°F)_—
Flow Rate
(ACFM) ___:
-
Velocity--
_ (ft/sec)
N/A
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Square/rectangle
❑ Other (describe):
Interior stack diameter (inches):
Interior stack width (inches):
❑ Upward with obstructing raincap
Interior stack depth (inches):
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
AvCOLORADO
lash bO.wmv..a
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
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.
Pollutants Controlled:
Vapor
❑ Recovery
Unit (VRU):
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed (emissions vented):
Make/Model:
❑ Combustion
Device:
Pollutants Controlled:
Rating: MMBtu/hr
Type: Make/Model:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature:
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
MMBtu /hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
Section 7 -Gas/Liquids Separation Technology Information (E£tP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Describe the separation process between the well and the storage tanks:
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
p� COLORADO
4 I L3�'� �°"""n,,
$5
tt
Benzene
71432
Permit Number:
AIRS ID Number:
/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form6.
If multiple emission control methods were identified in Section 6, the following table can be used to state the overall
(or combined) control efficiency (% reduction):
VOC
►verall Requested Control _
Efficiency
(%reducton in; emissions)
NOx
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
(7_,S58.234
11,8 8.234
VOC (. i l
s -5764E-04
Ib/BBL
ntena Pollutant Emissions_ Inventory
EPA Tanks
Uncontrolled
Emissions
(Tons/.year)
ontrolled
Emiss ons7,
(ronsTyear) ,
iric itrOlle-
Emissions
(Tons/year) _,
ontrolled
Emissions
(Tons/ear)
NOx..
CO
Non-Gntena Reportable Pollutant Emissions Inventory .
mission Facto
ctual AnnuaLEmissions
Toluene
Ethylbenzene
Xylene
n -Hexane
108883
100414
1330207
110543
Uncontrolled
:Basis
1. OE Oc1
0.19C$7
r•Ssa, c8
1.11E 07
9.23E 00
0.l1 OG
Ib/BBL
E&P and EPA Tanks
Uncontrolled
Emissions
(Poundslyear)
3"
0
Ib/BBL
Ib/BBL
E&P and EPA Tanks
E&P and EPA Tanks
18
ZS
3
Z5
3
jb/BBL
T Ib/BBL
E&P and. EPA Tanks
E&P and EPA Tanks
3
Zca
3
21.1
2,2,4-
Trimethylpentane
540841
c-- -0 t
87-9-1-E-6-7
Ib/BBL
E&P and EPA Tanks
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.
7 Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 5 I
--- co�ortkoo
hyCOLOR. DO
IMWa b Emle�vv,N
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. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature egally.
o /L
7 27-17
Au sized Person (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
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 $152.90 and the General Permit For more information or assistance call:
registration fee of $250, if applicable, to:
Colorado Department of Public Health and Small Business Assistance Program
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South Or visit the APCD website at:
Denver, CO 80246-1530
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
(303) 692-3175 or (303) 692-3148
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 6 I
COLORADO
nea.raamaatvawc
Nmal. b Montt
Crude Oil Storage Tank(s) APENl�J
Form APCD-210
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 maybe 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 tanks that store crude oil associated with oil and gas industry operations. If your emission
source does not fall into this category, there may be a more specific APEN available for your source (e.g. condensate
storage tanks, produced water storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/pacific/cdphe/air-permits. -
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:
/71✓EP67641-
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
12-3 /9P5 D / o'
AIRS ID Number:
Section 1 - Administrative Information
Company Name:
Site Name:
Discovery DJ Services LLC
Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Site Location
County: Weld
NAICS or SIC Code: 493190
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address: manya@discoverymidstream.com
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 APCD via e-mail to the address provided. •
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
368439
AWICOLORADO
114.411 o-fm+m
.41
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
✓❑ Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit exempt/grandfathered source
•
Additional Info Et Notes:
3 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:
For existing sources, operation began on:
For new or reconstructed sources, the projected
Normal Hours of Source Operation: 24
Storage tank(s) located at:
250,Ooo
-4.98;666 BBL EFR Stabilized Crude Oil Storage Tank
ev-
it 67119 -
start -up date is:
July 2018
hours/day 7 days/week 52
❑ Exploration E Production (EEP) site
weeks/year
❑✓ Midstream or Downstream (non EEeP) site
Will this equipment be operated in any NAAQS nonattainment area?
IS
Yes
•
No
Are Flash Emissions anticipated from these storage tanks?
■
Yes
p
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)•
805 series rules? If so, submit Form APCD-105:
Yes
No
p
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualEl
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
■
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 2 I Jiff
COLORADO
Deposer. ..�.M
Permit Number:
AIRS ID Number: / I
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
dual Annual Anio in_
(bbli year
__Crude Ail Throughput
From what year is the actual annual amount?
Average API gravity of sales oil: 42.6 degrees
❑ Internal floating roof
Tank design: ❑ Fixed roof
equestedAnnualPe ri it irnit4
(bblfyeprJ
29,200,000
RVP of sales oil: 7.0
❑✓ External floating roof
Storage
# of Ltquid Manifold Storage
`Vessels m Storage Tank
_ _ �_
Total Volume_of
Storage Tank
(Gbl)
lnstallatton Date =of Most
Date of First
Recent Sforage_Yessel in
Storage Tank (month/year)
Production
— (month/year).
Tank lD
Tk-202
= 1
250,000
NA
NA
urn
Wells Sernced'_by this -Storage Tank or Tank Batterys (EFP�SitesOnly)
Na =-- Newly Reported:Well
frikb Well
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
5 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
40.1930 N, -104.6097 W
OperatorStack-
ID No,
Discharge Height Above,_
GrolOC LeveL(feetJ
Temp..-
(°FA ..
Flow Rate``
i4ACFM)
Velocity
- (ft/sec) is
N/A
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
❑ Circular Interior stack diameter (inches):
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
-❑ Other (describe):
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
A'(/ICOLORADO
HNN 6 Eml.emrb
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Control Device Information
E Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
❑ Recovery
Unit (VRU):
Pollutants Controlled:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
❑ Combustion
Device:
Pollutants Controlled:
Rating: MMBtu/hr
Type: Make/Model:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature:
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
Section 7 -Gas/Liquids Separation Technology Information (E&P Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Describe the separation process between the well and the storage tanks:
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017 4 I AY
DeparaammlatPolAlc
COLORADO
Hiatt. EmLmuMN
Benzene
71432
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions 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 overall
(or combined) control efficiency (% reduction):
VOC
NOx
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
-riteria`Pollutant;Emissions Invent -6
controlled
missions
ons%year,) _
strolled
missions?
(Tonslyear)_
Uncontrolled
Emissions
(tons%year) -
Controlled
missions -
(Tdns%year)_
voc
6.15E-04
Ib/BBL
EPA Tanks
12,Q, 8.083
l2,$0.
NOx
Co
Non -Criteria
eportatle P0llutant'Enissions;inventory.=_
mission Factor°>>:
ctual AnnuatEmissionsv
Uncontrolled
=Basis
Ib/BBL
Source
(AP 42,
Mfg etc)
Uncontrolled, ;t
Emissions
(Poundsiyear`.)
ontrolled
missions:
?ounds%year)
9.02E-07
E&P and EPA Tanks
30
38
Toluene
108883
5.86E-07
lb/BBL
E&P and EPA Tanks
25
Ethylbenzene
Xylene
100414
7.85E-08
Ib/BBL
E&P and EPA Tanks
3
3
1330207
6.68E-08
Ib/BBL
E&P and EPA Tanks
3
3
n -Hexane
2,2,4-
Trimethylpentane
110543
540841
6.30E-06
5.73E-07
Ib/BBL
Ib/BBL
E&P and EPA Tanks
E&P and EPA Tanks
4,
Zc1
Zy
4 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.-
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-210 - Crude Oil 'Storage Tank(s) APEN - Revision 02/2017
C0L0R4Dic
5 a.,n.b.mruwc
IWII.b Ei.n.wsN
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. If this is a registration for coverage under General Permit GP08, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature oegally A( horized Person (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
Name (print)
Title
Check the appropriate box to request a copy of the:
Q 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 $152.90 and the General Permit
registration fee of $250, if applicable, to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
AvcoLORADO
Fugitive Component Leak
Emissions APEN - Form APCD-203
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 fugitive component leak emissions. If your emission source does not fall into this
category, there may be a different specialty APEN available for your operation (e.g. natural gas venting,
condensate tanks, paint booths, etc.). In addition, the General APEN (Form APCD- 200) is available if the specialty
APEN options do not meet your reporting needs. A list of specialty APENs is available on the Air Pollution Control
Division (APCD) website at www.colorado.Qov/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: /2.3 /7F5D / 006
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Discovery DJ Services LLC
Discovery Oil Terminal
Site Location: Section 25, T3N, R65W
Mailing Address: 7859 Walnut Hill Lane, Suite 335
(include Zip Code)
Dallas, TX 75230
Permit Contact: Manya Miller
E -Mail Address2:
manya@discoverymidstream.com
Site Location Weld
County:
NAICS or SIC Code: 493190
Phone Number: (214) 414-1980
i 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 APCD via e-mail to the address provided.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision
5/2017
368440
j��INOLORAEr.rtr�O
1 I 1/ISA, na�n ate
,4I
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
❑ Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $250 must be
submitted along with the APEN filing fee.
OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
- OR
APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
▪ APEN submittal for permit exempt/grandfathered source
Additional Info £t Notes:
3 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:
For existing sources, operation began on:
100,000 BBL EFR Stabilized Crude Oil Storage Tank
For new or reconstructed sources, the projected start-up date is: July 2018
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week
❑ Exploration a Production (EEtP) site
52
weeks /year
❑✓ Midstream or Downstream (non EEtP) site
Will this equipment be operated in any NAAQS nonattainment area?
Q
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
•
Yes
U
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•
p
Are you requesting ≥ 6 ton/yr VOC emission s (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
0
■
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 02/2017
a..v(COLORADO
2 �Y7
Nsuh6 ��LL
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
0 NEW permit OR newly -reported _ emission source (check one below)
-OR -
permit (check each box below that applies)
❑ MODIFICATION to existing ss or equipment ❑ Change company name ❑ Add point to existing permit
Change process s Other (describe below)
❑ Change permit limit
Transfer of ownership ❑
-OR-
APEN submittal for update only (Blank APENs will not be accepted)
❑ - ADDITIONAL PERMIT ACTIONS -
APEN submittal for permit exempt/grandfathered source
Additional Info ft Notes:
3 For transfer of ownership,
a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
For existing sources, operation began on:
date is: Jul 2018
For new or reconstructed sources, the projected start-up y
ck this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Che days/week
Normal Hours of Source
hours/ day
Operation: - —�
Facility Type:
[] Well Production Facility4
0 Natural Gas Compressor Station4
0 Natural Gas Processing Plant4
0✓ Other
(describe): Section VII.
When selecting the facility type, refer to definitions in Colorado Regulation No. 7,
Crude Oil Storage Facility
Form APCD 203- Fugitive Component Leak Emissions APEN - Revision
5/2017
weeks/year
®FIcor:ocro
Gas
.4
Permit Number: AIRS ID Number:
/ I
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Regulatory Information
What is the date that the equipment commenced construction?
January 2018
Will this equipment be operated in any NAAQS nonattainment area?5 2 Yes ❑ No
Will this equipment be located at a stationary source that is considered a ❑ Yes E No
Major Source of Hazardous Air Pollutant (HAP) emissions?
Are there wet seal centrifugal compressors or reciprocating compressors ❑ Yes ❑✓ No
located at this facility?
is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes E No
Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes 2 No
Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? ❑ Yes ❑✓ No
Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑ Yes No
Is this equipment subject to Colorado Regulation No. 7, Section XII.G? ❑ Yes ❑✓ No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑ Yes ❑r No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes 2 No
5 See http://www.colorado.gov/cdphe/state-implementation-plans-sips for which areas are designated as attainment/non-
attainment.
Section 5 - Stream Constituents
0 The required representative gas and liquid extended analysis (including BTEX) to support the data below has
been attached to this APEN form.
Use the following table to report the VOC and HAP weight % content of each applicable stream.
Benzene
(wt %)
Toluene
(wt %)__
Ethylbe•
nzeri
0.43
n Hexane
0.752
Heavy Oil
(or Heavy Liquid)
Light Oil
(or Light Liquid)
99.92
0.38
0.96
0.43
2.60
Water/Oil
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision
5/2017
COLORADO
}YW,b EmrLermsK
Permit Number:
MRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 Geographical Information
Attach a topographic site map showing location
Sec
tion 7 - Leak Detection and Repair (LDAR) and Control Information
Check the appropriate boxes to identify the LDAR program conducted at this site:
❑ LDAR per 40 CFR Part 60, Subpart KKK
76% ti ht liquid valve, 68% light liquid pump
❑ Monthly Monitoring - Control: 88% gas valve, g
0 Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump
❑ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa O Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 86% light liquid pump, 81%
connectors
❑ LDAR per Colorado Regulation No. 7,
Section XVII.F
❑ other': The operator or operator will perform quarterly AVO inspections, as
specified in the O&M Plan.
❑ No LDAR Program
6 Attach other supplemental plan to APEN form if needed.
onent Leak Emissions APEN - Revision
Form APCD-203 - Fugitive Comp
5/2017
COLORADO
4 1ff
Counts
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS'ID]
Section 8 - Emission Factor Information
Select which emission factors were used to estimate emissions below. If none apply, use the table below to
identify the emission factors used to estimate emissions. Include the units related to the emission factor.
❑r Table 2-4 was used to estimate emissions7.
❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions7.
Use the following table to report the component count used to calculate emissions. The component counts listed
in the following table are representative of:
0 Estimated Component Count
❑ Actual Component Count conducted on the following date:
uipment_
Emission Factor
Units
Heavy ,O
or HeavyTLiqui
Count8
Emission Factor
Units
t Oil orti
Count8
52
220
0
18
104
9
Emission Factor
Units
ater/Oi
Count8
Emission Factor
Units
LO -
7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R-
95-017).
s The count shall be the actual or estimated number of components in each type of service that is used to calculate -the "Actual
Calendar Year Emissions" below.
9 The Other equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals,
or valves.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision
r-
5iMrI
COLORADO
nWc®mmr.w=
5/2017
I.e. lErnrinmenurni
Permit Number:
AIRS ID Number:
I /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Criteria and Non -Criteria Pollutant Emisss onh�s APEN Information
form.
Attach all emission calculations and emission factor documentation
From what year is the following reported actual annual emissions data?
report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source:
Use the following table to
(Use the data reported in Section 8 to calculate these emissions.)
_ .:� ,.�I FmicciOn5G
actual emissions of individual non -criteria No
Does the nts (e.g. HAP- hazardous have any equal to or greater than 250 Yes
pollutants (e.g. air pollutant) emissions
lbs/year?
table to report the non criteria pollutant (HAP) emissions from source:
If yes, use the following - Re nested Annual Permit Eintsston Limtti
t.Actual Annual:,Emtsstons _ q ControUe8�°
Controlled9 - Uncontrolled (lbs/y ..
((6s/year)
Other: leave
10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started
r growth, ra operating,
component count
blank.should consider futuprocess 11 Requested values will become permit limitations. Requested limit(s)
variability, and gas composition variability.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision
5/2017
ICOLOWADO-
6 I AV
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 10 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true and correct.
/8,
Signature of Legally'Authorized erson (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
Name (print)
Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
El 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 $152.90 to: For more information or assistance call:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision
5/2017 7 L'D
COLORADO
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