DAQ-2025-002019

DAQE-AN102130002-25

{{$d1 }}

Gretsel Marshall
Chevron Pipe Line Company
651 South Redwood Road
North Salt Lake, UT 84054
[e-mail]

Dear Ms. Marshall:

Re: Approval Order: Administrative Amendment to Approval Order DAQE-AN0102130001-09 for a
10-Year Review and to Update Equipment
Project Number: N102130002

The attached Approval Order (AO) is issued pursuant to the Division of Air Quality conducting a 10-year
administrative review of this source and its respective AO. Chevron Pipe Line Company must comply
with the requirements of this AO, all applicable state requirements (R307), and Federal Standards.

The project engineer for this action is Dungan Adams, who can be contacted at [phone] or
[e-mail]. Future correspondence on this AO should include the engineer's name as well
as the DAQE number shown on the upper right-hand corner of this letter.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:DA:jg

cc: TriCounty Health Department

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Tim Davis
Interim Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

April 9, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

{{#s=Sig_es_:signer1:signature}}
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}}
{{#d2=date1_es_:signer1:date:format(date, "mmmm d, yyyy"):align(center)}}

APPROVAL ORDER
DAQE-AN102130002-25
Administrative Amendment to Approval Order
DAQE-AN0102130001-09 for a 10-Year Review and
to Update Equipment

Prepared By
Dungan Adams, Engineer
[phone]
[e-mail]

Issued to
Chevron Pipe Line Company - Hanna Pumping Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

April 9, 2025
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 4
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 6
ACRONYMS ................................................................................................................................. 7

DAQE-AN102130002-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Chevron Pipe Line Company Chevron Pipe Line Company - Hanna Pumping Station

Mailing Address Physical Address
651 South Redwood Road 40700 West 7000 North
North Salt Lake, UT 84054 Hanna, UT 84031

Source Contact UTM Coordinates
Name: Gretsel Marshall 520,536 m Easting
Phone: [phone],472,294 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 4612 (Crude Petroleum Pipelines)

SOURCE INFORMATION
General Description
Chevron Pipe Line Company (Chevron) owns and operates the Hanna Pumping Station located in Hanna,
Duchesne County. The facility receives crude oil, condensable hydrocarbons, and black wax throughput
from the company-owned pipeline on its way to Salt Lake City. The facility serves as a buffer to pipeline
operations, allowing production to fluctuate while maintaining a consistent flow within the pipeline. The
facility includes the petroleum pumping station, storage tanks, and various comfort heaters.

NSR Classification
10-Year Review

Source Classification
Located in Attainment Area
Duchesne County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), Kb: Standards of Performance for Volatile Organic Liquid Storage Vessels
(Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or
Modification Commenced After July 23, 1984
DAQE-AN102130002-25
Page 4

Project Description
This is a 10-Year Review for Chevron's Hanna Pumping Station to update contact information, permit
formatting, and rule applicability.

The source has also requested the following updates to the approved equipment list:

1. Remove Tank 530.
2. Change Tanks 510 and 520 from "external floating roof storage tanks" to "internal floating roof storage
tanks."

SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
Volatile Organic Compounds -2.60 9.67

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
2,2,4-Trimethylpentane (CAS #540841) -6 14
Benzene (Including Benzene From Gasoline) (CAS #71432) -4 36
Ethyl Benzene (CAS #100414) 0 20
Hexane (CAS #110543) -92 288
Toluene (CAS #108883) -18 62
Xylenes (Isomers And Mixture) (CAS #1330207) -8 92
Change (TPY) Total (TPY)
Total HAPs -0.07 0.26

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8]
DAQE-AN102130002-25
Page 5

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]

SECTION II: PERMITTED EQUIPMENT
II.A THE APPROVED EQUIPMENT II.A.1 Hanna Pumping Station
II.A.2 Equipment Leaks Various process connection/process control device equipment leaks II.A.3 Tank 510 2,520,000-gallon Internal Floating Roof Storage Tank (1973)
II.A.4 Tank 520 2,520,000-gallon Internal Floating Roof Storage Tank (1972) II.A.5 Tank 111 1,680,000-gallon Internal Floating Roof Storage Tank (1949)
II.A.6 Comfort Heaters Fuel: Natural Gas Rating: Less than 5 MMBtu/hr each *Listed for informational purposes only

DAQE-AN102130002-25
Page 6

SECTION II: SPECIAL PROVISIONS
II.B REQUIREMENTS AND LIMITATIONS

II.B.1.a The owner/operator shall not exceed the following throughputs: A. 9,166,610 barrels of crude oil throughput per rolling 12-month period. B. 1,896,540 barrels of black wax condensate mix throughput per rolling 12-month period. C. 4,741,350 barrels of condensate throughput per rolling 12-month period. [R307-401]
II.B.1.a.1 The owner/operator shall:

A. Determine throughput from company and/or customer billing records.

B. Record crude oil throughput on a monthly basis.

C. Use the throughput data to calculate a new rolling 12-month total by the 20th day of
each month using data from the previous 12 months.

D. Keep records of crude oil throughput for all periods the facility is in operation.

[R307-401-8]

II.B.1.b The owner/operator shall not allow visible emissions from any stationary point or fugitive emission source on site to exceed 20% opacity. [R307-201-3, R307-205-4]
II.B.1.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Appendix A, Method 9. [R307-201-3]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:
Supersedes AO DAQE-AN0102130001-09 dated April 9, 2009 Is Derived From NOI dated October 4, 2024 Incorporates Additional Information dated January 22, 2025 Incorporates Additional Information dated March 3, 2025
DAQE-AN102130002-25
Page 7

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document:

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by Environmental Protection Agency to classify
sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98,
Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal Division of Air Quality use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i)
GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818-
12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DAQE-

RN102130002
March 19, 2025

Gretsel Marshall
Chevron Pipe Line Company
651 South Redwood Road
North Salt Lake, UT 84054
[e-mail]

Dear Gretsel Marshall,

Re: Engineer Review - 10-Year Review and Permit Updates:
Administrative Amendment to Approval Order DAQE-AN0102130001-09 for a 10-Year Review
and to Update Equipment
Project Number: N102130002

The DAQ requests a company representative review and sign the attached Engineer Review (ER). This
ER identifies all applicable elements of the New Source Review (NSR) permitting program. Chevron
Pipe Line Company should complete this review within 10 business days of receipt.

Chevron Pipe Line Company should contact Dungan Adams at [phone] if there are questions or
concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email
Dungan Adams at [e-mail] the signed cover letter. Upon receipt of the signed cover
letter, the DAQ will prepare an Approval Order (AO) for signature by the DAQ Director.

If Chevron Pipe Line Company does not respond to this letter within 10 business days, the project will
move forward without source concurrence. If Chevron Pipe Line Company has concerns that cannot be
resolved and the project becomes stagnant, the DAQ Director may issue an Order prohibiting
construction.

Approval Signature _____________________________________________________________
(Signature & Date)

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of
Environmental Quality

Tim Davis
Interim Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director
State of Utah

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor
Luke Johnson Digitally signed by Luke Johnson
Date: 2025.04.02 06:39:27 -06'00'

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION

Project Number N102130002
Owner Name Chevron Pipe Line Company
Mailing Address 651 South Redwood Road
North Salt Lake, UT, 84054

Source Name Chevron Pipe Line Company- Hanna Pumping Station
Source Location 40700 West 7000 North
Hanna, UT 84031

UTM Projection 520,536 m Easting, 4,472,294 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 4612 (Crude Petroleum Pipelines)

Source Contact Gretsel Marshall
Phone Number [phone]
Email [e-mail]

Billing Contact Gretsel Marshall
Phone Number [phone]
Email [e-mail]

Project Engineer Dungan Adams, Engineer
Phone Number [phone]
Email [e-mail]

Notice of Intent (NOI) Submitted October 4, 2024
Date of Accepted Application January 23, 2025

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 2
SOURCE DESCRIPTION

General Description
Chevron Pipe Line Company (Chevron) owns and operates the Hanna Pumping Station located in
Hanna, Duchesne County. The facility receives crude oil, condensable hydrocarbons, and black
wax throughput from the company owned pipeline on its way to Salt Lake City. The facility
serves as a buffer to pipeline operations, allowing production to fluctuate while maintaining a
consistent flow within the pipeline. The facility includes the petroleum pumping station, storage
tanks, and various comfort heaters.

NSR Classification:
10 Year Review

Source Classification
Located in Attainment Area
Duchesne County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), Kb: Standards of Performance for Volatile Organic Liquid Storage Vessels
(Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or
Modification Commenced After July 23, 1984

Project Proposal
Administrative Amendment to Approval Order DAQE-AN0102130001-09 for a 10-Year Review
and to Update Equipment

Project Description
This is a 10-Year Review for Chevron's Hanna Pumping Station to update contact information,
permit formatting, and rule applicability.

The source has also requested the following updates to the approved equipment list:
1. Remove Tank 530
2. Change Tanks 510 and 520 from "external floating roof storage tanks" to "internal floating roof
storage tanks"

EMISSION IMPACT ANALYSIS
This is a 10-Year Review. No equipment is being added, and no changes are being made which will result in an
emission increase. Therefore, modeling is not required. [Last updated March 19, 2025]

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 3
SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
Volatile Organic Compounds -2.60 9.67

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
2,2,4-Trimethylpentane (CAS #540841) -6 14
Benzene (Including Benzene From Gasoline) (CAS #71432) -4 36
Ethyl Benzene (CAS #100414) 0 20
Hexane (CAS #110543) -92 288
Toluene (CAS #108883) -18 62
Xylenes (Isomers And Mixture) (CAS #1330207) -8 92
Change (TPY) Total (TPY)
Total HAPs -0.07 0.26

Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 4
Review of BACT for New/Modified Emission Units

1. BACT review regarding Petroleum Pumping Station
This is a 10-Year Review. No equipment is being added, and no changes are being made which
will result in an emission increase. Therefore, a BACT analysis is not required. [Last updated
March 19, 2025]

SECTION I: GENERAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available
to the Director which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-
401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-
150]

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 5
SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

II.A THE APPROVED EQUIPMENT

II.A.1 Hanna Petroleum Pumping Station

II.A.2 Equipment Leaks
Various process connection/process control device equipment leaks

II.A.3 Tank 510
2,520,000-gallon Internal Floating Roof Storage Tank (1973)

II.A.4 Tank 520
2,520,000-gallon Internal Floating Roof Storage Tank (1972)

II.A.5 Tank 111
1,680,000-gallon Internal Floating Roof Storage Tank (1949)

II.A.6 Comfort Heaters
Fuel: Natural Gas
Rating: Less than 5 MMBtu/hr each
*Listed for informational purposes only

SECTION II: SPECIAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

II.B REQUIREMENTS AND LIMITATIONS

II.B.1.a
NEW
The owner/operator shall not exceed the following throughputs:

A. 9,166,610 barrels of crude oil throughput per rolling 12-month period.

B. 1,896,540 barrels of black wax condensate mix throughput per rolling 12-month
period.

C. 4,741,350 barrels of condensate throughput per rolling 12-month period. [R307-401]

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 6
II.B.1.a.1
NEW
The owner/operator shall:

A. Determine throughput from company and/or customer billing records.

B. Record crude oil throughput on a monthly basis.

C. Use the throughput data to calculate a new rolling 12-month total by the 20th day of
each month using data from the previous 12 months.

D. Keep records of crude oil throughput for all periods the facility is in operation. [R307-
401-8]

II.B.1.b
NEW
The owner/operator shall not allow visible emissions from any stationary point or fugitive
emission source on site to exceed 20% opacity. [R307-201-3, R307-205-4]

II.B.1.b.1
NEW
Opacity observations of emissions from stationary sources shall be conducted in accordance
with 40 CFR 60, Appendix A, Method 9. [R307-201-3]

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 7
PERMIT HISTORY

When issued, the approval order shall supersede (if a modification) or will be based on the
following documents:

Supersedes AO DAQE-AN0102130001-09 dated April 9, 2009
Is Derived From NOI dated October 4, 2024
Incorporates Additional Information dated January 22, 2025
Incorporates Additional Information dated March 3, 2025

REVIEWER COMMENTS

1. Comment regarding 10-Year Review:
This is a 10-Year Review on Chevron's Hanna Pumping Station AO (DAQE-AN0102130001-09).
The mailing address and source contact information have been updated. The permit conditions have
been updated to the current format.

The source has requested to remove and update equipment so that the Approved Equipment list
accurately reflects the equipment on site. The source has requested to remove Tank 530 (listed in
AO DAQE-AN0102130001-09) and change Tanks 510 and 520 from "External Floating Roof
Storage Tanks" to "Internal Floating Roof Storage Tanks". None of these changes to equipment will
result in increases of any air pollutants and no undocumented equipment changes or replacements
were ever indicated by DAQ compliance. Therefore, these updates will be included as part of this
10-year review.

The source requested that Tank 530 (2,520,000-gallon internal floating roof storage tank) be
removed from the updated AO as it was never installed at the facility. The NOI for the 2009 AO lists
Tank 530 estimated emissions as 1.38 tons per year (TPY) of VOCs and 0.04 TPY of HAPs. Tank
530 is removed from the Approved Equipment list and its emissions are removed from the Summary
of Emissions table.

The source indicated that Tanks 520 and 510 are "Internal Floating Roof Tanks" not "External
Floating Roof Tanks." Using parameters from the 2009 NOI, emission routine losses were estimated
for Tank 510, once assuming an internal floating roof, and once assuming an external floating roof.
Emissions were estimated using EPA TANKS 5.1 and parameters listed in the 2009 NOI. The
current emissions estimated from Tank 510 assuming an external floating roof were similar to the
emissions estimated for Tank 510 in the 2009 NOI. The emissions estimated from Tank 510
assuming an internal floating roof were roughly 40% less than the current external floating roof
estimate. Tanks 510 and 520 are both 2,520,00-gallon storage tanks with similar properties.
Switching from "External Floating Roof Storage Tanks" to "Internal Floating Roof Storage Tanks"
will reduce both VOCs and HAPs. To maintain a conservative site-wide emission estimate, VOC
and HAP emissions from Tanks 510 and 520 were reduced by 30%. The 2009 NOI lists Tank 510
estimated emissions as 2.27 TPY of VOCs and 0.06 TPY of HAPs. The change to "Internal Floating
Roof Storage Tanks" will conservatively result in a reduction of 0.68 TPY of VOCs and 0.02 TPY of
HAPs. The 2009 NOI lists Tank 520 estimated emissions as 1.81 TPY of VOCs and 0.06 TPY of
HAPs. The change to "Internal Floating Roof Storage Tanks" will conservatively result in a
reduction of 0.54 TPY of VOCs and 0.02 TPY of HAPs. Tanks 510 and 520 are updated to "Internal
Floating Roof Storage Tanks" in the Approved Equipment list and the reductions are included in the
Summary of Emissions table.

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 8
The requested equipment changes will conservatively result in a net decrease of 2.60 TPY of VOCs
and 0.07 TPY of HAPs. The source was previously estimated to produce 0.005 TPY of Naphthalene.
After removing the emissions from Tank 530 and updating the emissions from Tanks 510 and 520,
the source is estimated to produce 0.004 TPY of Naphthalene. Because this rounds to 0.00 TPY
using two decimal places, Naphthalene has been removed from the Summary of Emissions table.
[Last updated March 19, 2025]

2. Comment regarding Federal Subpart Applicability:
NSPS
40 CFR 60 Subpart Kb (Standards of Performance for Volatile Organic Liquid Storage Vessels
(Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or
Modification Commenced After July 23, 1984, and On or Before October 4, 2023) applies to each
storage vessel with a capacity greater than or equal to 75 cubic meters that is used to store volatile
organic liquids (VOL) for which construction, reconstruction, or modification is commenced after
July 23, 1984, and on or before October 4, 2023. The four (4) storage tanks at the facility
commenced construction after July 23, 1984, and on or before October 4, 2023, have a capacity
greater than 75 cubic meters, and store VOLs. Therefore, NSPS Subpart Kb applies to the source.
NSPS Subpart Kb requires the source to maintain storage tank dimensions for the life of the tank,
regardless of the tank size or vapor pressure of the contents.

MACT
40 CFR 63 Subpart R (National Emission Standards for Gasoline Distribution Facilities (Bulk
Gasoline Terminals and Pipeline Breakout Stations) applies to each bulk gasoline terminal and each
pipeline breakout station as defined in the subpart that are located at a major source. The facility
meets the definition of a pipeline breakout station; however, it is not a major source. Therefore,
MACT Subpart R does not apply to the source. [Last updated January 28, 2025]

3. Comment regarding Title V Applicability:
Title V of the 1990 Clean Air Act (Title V) applies to the following:
1. Any major source
2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act,
Standards of Performance for New Stationary Sources;
3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous
Air Pollutants.
4. Any Title IV affected source.

This source is not a major source and is not a Title IV source. This source is subject to 40 CFR 60
Subpart Kb; however, the source is only subject to a record keeping requirement that does not
support a limitation. Since the source is not subject to a standard, limitation, or other requirement
under Section 111 of the Act, Title V does not apply to the Hanna Pumping Station. [Last updated
February 18, 2025]

Engineer Review N102130002: Chevron Pipe Line Company- Hanna Pumping Station
March 19, 2025
Page 9
ACRONYMS
The following lists commonly used acronyms and associated translations as they apply to this
document:
40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by EPA to classify sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal UDAQ use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)
GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/HR Pounds per hour
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

Tank ID Tank Type Meteorological Location Chemical Name Annual Standing Losses (lb/yr)
Tank 510 (Ex)External Floating Roof Tank Salt Lake City, UT Midcontinent Crude Oil RVP 5 2720.528508
Tank 510 (Int)Internal Floating Roof Tank Salt Lake City, UT Midcontinent Crude Oil RVP 5 538.0821495
Annual Rim Seal Losses (lb/yr)Annual Deck Seam Losses (lb/yr)Annual Deck Fitting Losses (lb/yr)Annual Working Losses (lb/yr)
436.383276 0 2284.145232 2613.989142
171.177243 0 366.9049065 2613.989142
Annual Total Losses (lb/yr)
5334.517651
3152.071292
0.59
Tank ID Tank Type Descriptio City, State Company Chemical NAnnual Rim Seal Facto Seal Facto Annual Av Seal-relate Annual Ave Annual Av
Tank 510 (External Fl , Midcontin 436.3833 0.6 0.4 8.3 1 0.058591 515.318
Tank 510 (Internal Flo , Midcontin 171.1772 1.6 0.3 0 1.6 0.056308 513.5509
Annual Av Liquid Bulk Tank Paint Tank Paint Annual Ave Annual Pro Annual Wi Number of Effective C Annual Ne Annual Sum Annual Ave Annual Av
2.639318 511.65 0.25 0.25 50 0.4 2613.989 2.6E+08 4896 0.006 7.1
2.547478 511.65 0.25 0.25 50 0.4 2613.989 0 2.6E+08 4896 0.006 7.1
Annual De Annual Tot Annual De Deck Seam Deck Seam Deck Seam Length Factor (ft/sqft)
2284.145 1949.24 0 0
366.9049 325.8 0 0
Tank ID Tank Type Descriptio City, State Company Meteorolo Tank Shap Shell Lengt Shell Side Shell Side Shell Side 2 Shell Heigh Shell Diam
Tank 510 (External Fl , Salt Lake C 48 95
Tank 510 (Internal Flo , Salt Lake C 48 95
Maximum Average Li Minimum Is Tank He Typical Ma Typical Ave Typical Mi Number of Roof Type Vacuum Se Pressure S Vapor Spa Is Tank Ins
Pontoon
Is Tank Ins Tank Cone Tank Dome Is Tank Equ Control De Liquid Bulk Liquid Bulk Tank Botto Cone-Shap Liquid Hee Minimum Self Suppo Number of
User Input 511.65 flat none
User Input 511.65 flat none Yes
Effective C Internal Sh Primary SeSecondary Seal Fit Deck Type Tank ConstDeck Cons Deck SeamPanel/She Panel Leng Shell ColorShell Cond
Light Rust Mechanica Rim-mounAverage-fi Welded Welded White Average
Light Rust Mechanica Shoe-mou Average-fi Welded Welded White Average
Roof ColorRoof Condition
White Average
White Average
Tank ID Tank Type Descriptio City, State Company Access HatAccess Hat Fixed Roof Fixed Roof Unslotted Unslotted Slotted Gu Slotted Gu
Tank 510 (External Fl , Bolted cov 1 Ungaskete 1
Tank 510 (Internal Flo , Unbolted c 1 Round pip 1 0 0
Gauge-floa Gauge-floa Gauge-hat Gauge-hat Vacuum BrVacuum Br Deck DrainDeck Drain Deck Leg Deck Leg CDeck Leg o Deck Leg o Rim Vent
Unbolted c 1 Weighted 1 Weighted 1 Weighted
Unbolted c 1 0 Weighted 1 0 Adjustable 0
Rim Vent CLadder WeLadder We Ladder-slo Ladder-slo Deck Leg ( Deck Leg C Deck Leg ( Deck Leg Count (Double-deck roofs and center area o
1 Adjustable Adjustable
1 0 0
of pontoon roofs)
Tank ID Meteorolo Annual Ave Annual Av Annual Ave Annual Av Annual Av January Av January Av January Av January Av February A February A
Tank 510 (Salt Lake C 12.62 63.3 42.9 8.3 1442 37.7 23.3 6.7 596 43.1 26.9
Tank 510 (Salt Lake C 12.62 63.3 42.9 8.3 1442 37.7 23.3 6.7 596 43.1 26.9
February A February A March Ave March Ave March Ave March Ave April Avera April Avera April Avera April Avera May Avera May Avera May Avera
7.2 877 53.4 34.4 8.7 1348 60.3 40.2 9.6 1685 71.5 49 8.9
7.2 877 53.4 34.4 8.7 1348 60.3 40.2 9.6 1685 71.5 49 8.9
May Avera June Avera June Avera June Avera June Avera July Averag July Averag July Averag July Averag August Ave August Ave August Ave August Ave
2071 81.8 57.3 9.2 2336 92.4 66.4 8.9 2338 90.1 64.9 9.6 2052
2071 81.8 57.3 9.2 2336 92.4 66.4 8.9 2338 90.1 64.9 9.6 2052
Septembe Septembe Septembe Septembe October Av October Av October Av October Av November November November November December
78.9 54.3 8.7 1689 64 42.2 8.1 1144 48.7 31.1 7.4 700 38
78.9 54.3 8.7 1689 64 42.2 8.1 1144 48.7 31.1 7.4 700 38
December December December Average Daily Total Insolation Factor (Btu/ft2/day)
24.1 7.2 469
24.1 7.2 469
Tank ID Input TypeChemical C Sum of Inc Working Lo Annual Ch Annual Spe Annual Co Annual Th Annual Sum January Ch January Sp January Co
Tank 510 (Enter Annu Petroleum User Input Midcontin 4896
Tank 510 (Enter Annu Petroleum User Input Midcontin 4896
January ThJanuary Su February C February S February C February TFebruary S March Che March Spe March Com March Thr March Sum April Chem
April Speci April Comp April ThrouApril Sum May Chem May Speci May Comp May ThrouMay Sum o June Chem June Speci June Comp June Throu
June Sum o July Chemi July Specia July Comp July Throu July Sum o August Che August Spe August Co August ThrAugust Sum Septembe Septembe
Septembe Septembe Septembe October Ch October Sp October Co October ThOctober Su November November November November November
December December December December December Sum of Increases/Decreases in Liquid Level (ft/yr)
9/22/21, 11:25 AM OPCE Inspection Memo
OPCE Inspection Memo
Submitted by: chrisljensen
Submitted time: Sep 22, 2021, 11:23:46 AM
Date DAQC-1257-2021
Sep 20, 2021, 11:11:00 AM
Inspector Name
Chris Jensen
Site ID
10213
County
Duchesne (13)
Location
Lat: 40.401 Lon: -110.758
Ha nna 9
Bureau of Land Manag...
Operator
Other
Other DAQC-2021-012527
Chevron USA Pipeline
https://survey123.arcgis.com/surveys/55cfdeb5cd1c44f8bebc9db8ab170d39/data?objectids=352 1/3
9/22/21, 11:25 AM OPCE Inspection Memo
Source Name
Hanna pumping Station
Source Type
Pig Launcher / Receiver
API #
Is this site controlled?
Uncontrolled
Is this Location Accessible?
Yes
Are there visible emissions?
No visible emissions detected.
Are there Audible or Olfactory Indications?
No AVO indications detected.
Did an OGI camera survey reveal leaks?
No OGI emission found.
Is there unapproved equipment?
No unapproved equipment found.
Did you meet a company representative onsite?
Yes
Issues or Comments
No issues found.
https://survey123.arcgis.com/surveys/55cfdeb5cd1c44f8bebc9db8ab170d39/data?objectlds=352 2/3
9/22/21, 11:25 AM OPCE Inspection Memo
Compliance Status
Compliant
Planned or Immediate Response
None, In compliance at time of inspection.
Future inspections should be.....
Decreased / less frequent.
Additional comments
This source is a pipeline station. They seem to have means of pigging set up here and very large concrete
vaults with floating roofs for storage. This source is very well kept and exceptionally clean. There is very little
here that could be observed for compliance. The DAQ recommends less frequent inspections .
("44,en
Chris Jensen Rik Ombach
https://survey123.arcgis.com/surveys/55cfdeb5cd1c44f8bebc9db8ab170c139/data?objectlds=352 3/3
Tank 530 Tank 111 Tank 510 Tank 520 Total Tanks
VOCs 1.38 0.94 2.27 1.81 6.40
HAPs 0.040395 0.025021 0.06255 0.062235 0.19
2,2,4-Trimethylpentane 0.00092 0.000625 0.00137 0.001145 0.00
Benzene 0.00275 0.00166 0.0043 0.004475 0.01
Biphenyl 0.00023 0.000185 0.00031 0.000095 0.00
Cresol 0.000355 0.000285 0.00048 0.00015 0.00
Ethybenzene 0.001205 0.00093 0.001665 0.00071 0.00
Hexane 0.024205 0.013175 0.03944 0.048375 0.13
Isopropyl benzene 0.000315 0.00025 0.00043 0.000155 0.00
Naphthalene 0.00055 0.00044 0.00074 0.00023 0.00
Toluene 0.004125 0.00298 0.005915 0.00368 0.02
Xylenes 0.00574 0.004491 0.0079 0.00322 0.02
Tank 111 Tank 510 Tank 520 Total Tanks Fugatives
VOCs 0.94 1.589 1.267 3.80 5.87
HAPs 0.024301 0.042931 0.0432845 0.11 0.147805
2,2,4-Trimethylpentane 0.000625 0.000959 0.0008015 0.00 0.00417
Benzene 0.00166 0.00301 0.0031325 0.01 0.009925
Ethybenzene 0.00093 0.0011655 0.000497 0.00 0.00693
Hexane 0.013175 0.027608 0.0338625 0.07 0.06894
Naphthalene 0.00044 0.000518 0.000161 0.00 0.003345
Toluene 0.00298 0.0041405 0.002576 0.01 0.02114
Xylenes 0.004491 0.00553 0.002254 0.01 0.033355
Emissions (tons/year)
Emissions (tons/year)
Fugatives Site-wide
5.87 12.27
0.15327 0.34
0.00417 0.01
0.009925 0.02
0.00141 0.00
0.002175 0.00
0.00693 0.01
0.06894 0.19
0.00188 0.00
0.003345 0.005
0.02114 0.04
0.033355 0.05
Site-wide
9.666
0.258
0.007
0.018
0.010
0.144
0.004 Previously included in permit, now emission estimate is less than 0.005 tpy
0.031
0.046

Dungan Adams <[e-mail]>
Review of Chevron's Hanna Pumping Station DAQ Air Permit
7 messages
Dungan Adams <[e-mail]>Wed, Jan 22, 2025 at 1:29 PM
To: [e-mail]
Hi Gretsel,
My name is Dungan Adams and I am an environmental engineer for the Utah Division of Air Quality (DAQ). I am reaching
out about Chevron's air permit for the Hanna Pumping Station (Attached as DAQE-AN0102130001-09).
The DAQ reviews older permits to update contact information and check to see if the facility is still operational. The Hanna
Pumping station was operational in 2021 based on a compliance inspection memo, but please let me know if this has
changed.
Please let me know if the following contact information needs to be updated:
Mailing Address:
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
I found your contact information listed on a recently approved Chevron Pipeline air permit, however if there is someone
who is better suited to help with my review, could you please forward this message to them?
Let me know if you have any questions and thank you for your help.
Thanks,
Dungan
--

Dungan Adams
Environmental Engineer | Minor NSR Section
M: [phone]
airquality.utah.gov
DAQE-AN0102130001-09.pdf
56K
Marshall, Gretsel <[e-mail]>Wed, Jan 22, 2025 at 2:48 PM
To: Dungan Adams <[e-mail]>
Hi Dungan,
4/2/25, 9:48 AM State of Utah Mail - Review of Chevron's Hanna Pumping Station DAQ Air Permit
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r1495998040162054846&simpl=msg-a:r-566309110606927…1/4

Yes, the facility is still operational, and I am the correct contact replacing Jim Robbins. My address is:

Chevron Pipe Line Company
651 S Redwood Road
North Salt Lake, UT 84054

Best,

Gretsel Marshall
Lead Environmental and Regulatory Specialist | CPP
[e-mail]
651 S Redwood Road
North Salt Lake, UT 84054
Mobile [phone]

From: Dungan Adams <[e-mail]>
Sent: Wednesday, January 22, 2025 1:29 PM
To: Marshall, Gretsel <[e-mail]>
Subject: [**EXTERNAL**] Review of Chevron's Hanna Pumping Staon DAQ Air Permit

Be aware this external email contains an attachment and/or link.
Ensure the email and contents are expected. If there are concerns, please submit suspicious messages to the Cyber Intelligence
Center using the Report Phishing button.
[Quoted text hidden]
Dungan Adams <[e-mail]>Wed, Jan 22, 2025 at 3:41 PM
To: "Marshall, Gretsel" <[e-mail]>
Great. Thanks for getting back to me so quickly!
Thanks,
Dungan
[Quoted text hidden]
Dungan Adams <[e-mail]>Tue, Feb 18, 2025 at 12:29 PM
To: "Marshall, Gretsel" <[e-mail]>
4/2/25, 9:48 AM State of Utah Mail - Review of Chevron's Hanna Pumping Station DAQ Air Permit
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r1495998040162054846&simpl=msg-a:r-566309110606927…2/4
Hi Gretsel,
Attached is the draft permit for Chevron's Hanna Pumping Station. Please review the draft and let me know if you have
any questions. If everything looks good please sign the cover page and return the document to me.
Thanks,
Dungan
[Quoted text hidden]
RN102130002.rtf
1469K
Marshall, Gretsel <[e-mail]>Mon, Mar 3, 2025 at 3:02 PM
To: Dungan Adams <[e-mail]>
Hi Dungan,

Thank you for sending over the draft permit for Chevron's Hanna Pumping Station. Upon our review, we
identified a few clerical errors on page 5:

II.A.3 Tank 510 should be Internal Floating Roof
II.A.4 Tank 520 should be Internal Floating Roof
II.A.6 Tank 530 was never built and should be removed from the equipment inventory

Appreciate your time and the review. Please reach out with any questions.

Gretsel Marshall
Lead Environmental and Regulatory Specialist | CPP
[e-mail]
Mobile [phone]
[Quoted text hidden]
Dungan Adams <[e-mail]>Thu, Mar 20, 2025 at 9:30 AM
To: "Marshall, Gretsel" <[e-mail]>
Hi Gretsel,
4/2/25, 9:48 AM State of Utah Mail - Review of Chevron's Hanna Pumping Station DAQ Air Permit
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r1495998040162054846&simpl=msg-a:r-566309110606927…3/4
Attached is the updated draft permit for your review. The changes are highlighted.
I have removed Tank 530 and updated Tanks 510 and 520 to internal floating roof storage tanks. If you have any
questions about the methodology used to determine the emissions decreases from these equipment changes please let
me know and I can provide a more thorough explanation.
Let me know if you have any questions. If everything looks good, please sign the cover page and return the document to
me.
Thanks,
Dungan
[Quoted text hidden]
RN102130002.rtf
1474K
Marshall, Gretsel <[e-mail]>Wed, Apr 2, 2025 at 6:42 AM
To: Dungan Adams <[e-mail]>
Cc: "Johnson, Luke" <[e-mail]>
Dungan,

Thank you for your time and your review. The digitally signed copy is attached, please let me know if you
will need a wet signed copy as well.

Thanks,
[Quoted text hidden]
RN102130002.pdf
266K
4/2/25, 9:48 AM State of Utah Mail - Review of Chevron's Hanna Pumping Station DAQ Air Permit
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r1495998040162054846&simpl=msg-a:r-566309110606927…4/4
Dungan Adams <[e-mail]>
10-Year Reviews
1 message
Alan Humpherys <[e-mail]>Fri, Oct 4, 2024 at 9:29 AM
To: Dungan Adams <[e-mail]>
Dungan,
Can you please process the following 10-year reviews?
Site #1: 14346
Peer: EQ
Old AO: DAQE-AN0143460001-11 dated 5/18/2011
Site #2: 10213
Peer: Tim
Old AO: DAQE-AN0102130001-09 dated 4/9/2009
Site #3: 13071
Peer: Dylan
Old AO: DAQE-AN0130710004-09 dated 9/9/2009
Site #4: 11640
Peer: Tim
Old AO: DAQE-AN0116400002-09 dated 9/10/2009
Site #5: 14227
Peer: Christine
Old AO: DAQE-AN0142270001-09 dated 9/17/2009
Site #6: 10645
Peer: Christine
Old AOs: DAQE-278-94, DAQE-011-90, AO dated 2/20/86
Thanks,
Alan
--
Alan Humpherys
Manager | Minor NSR Section
P: [phone]
F: [phone]
airquality.utah.gov
Emails to and from this email address may be considered public records and thus subject to Utah GRAMA
requirements.
1/23/25, 2:16 PM State of Utah Mail - 10-Year Reviews
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-f:1811997790959911347&simpl=msg-f:1811997790959911347 1/1
State of Utah
JON M. HUNTSMAN, JR.
Governor
GARY HERBERT
Lie11te11am Go,•emor
April 9. 2009
Jim Robbins
Department of
Environmental Quality
William J. Sinclair
Acting Exl'rntive Director
DIVISION OF AIR QUALITY
Cheryl Heying
Director
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
Dear Mr. Robbins:
Re: Approval Order: Hanna Petroleum Pipeline Pumping Station
Duchesne County; CDS B; Attainment Area, NSPS (Part 60)
Project Number: N010213-0001
au ------
DAQE-AN0 102130001-09
The attached document is the Approval Order for the above-referenced project. Future correspondence
on this Approval Order should include the engineer's name as well as the DAQE number as shown on the
upper right-hand corner of this letter. The project engineer for this action is Tim DeJulis, who may be
reached at [phone].
Sincerely,
M!He~uti~ y
Utah Air Quality Board ve tJtat
MCH:TDJ:dn
cc: TriCounty Health Department
DAQ-2009-010253
150 North 1950 West • Salt Lake City. UT
Mailing Address: P.O. Box 144820 • Salt Lake City. UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. (80 1) 536-4414
www.deq.111nh. t:m'
Primed un 100'~ recyckd paper
STATE OF UTAH
Department of Environmental Quality
Division of Air Quality
APPROVAL ORDER: Hanna Petroleum Pipeline Pumping Station
Prepared By: Tim DeJulis, Engineer
Phone: [phone]
Email: [e-mail]
APPROVAL ORDER NUMBER
DAQE-AN0102130001-09
Date: April 9, 2009
Hanna Pumping Station
Source Contact:
Mr. Jim Robbins, Environmental Specialist
Phone: [phone]
~~ry;j}(J
Executive Secretary
Utah Air Quality Board
Abstract
Chevron USA Pipeline Company has requested permission to operate the Hanna petroleum pumping
station as a stationary area source. The Hanna station receives crude oil, condensible hydrocarbons, and
black wax throughput from the company owned pipeline on its way to Salt Lake City. The Hanna station
serves as a buffer to pipeline operations allowing production to ebb and flow while at the same time
maintaining a consistent throughput within the pipeline.
Plant equipment includes four storage tanks (one with 1,680,000 gallon capacity and three with 2,520,000
gallon capacity), electric pump motors, and various comfort heating equipment items rated less than
5,000,000 Btu/hr each.
The emissions, in tons per year, will be as follows:
VOC = 12.27, HAPs = 0.33
This air quality AO authorizes the project with the following conditions and failure to comply with any of
the conditions may constitute a violation of this order. This AO is issued to, and applies to the following:
Name of Permittee: Permitted Location:
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
Chevron USA Pipeline Company: Hanna
Pumping Station
40700 West 7000 North
Hanna, UT 84031
UTM coordinates: 520,536 m Easting, 4,472,294 m Northing
4612 (Crude Petroleum Pipelines)
I.l
I.2
I.3
1.4
I.5
SIC code:
Section I: GENERAL PROVISIONS
All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]
The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401]
All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Executive Secretary or Executive Secretary's
representative upon request, and the records shall include the two-year period prior to the date of
the request. Unless otherw ise specified in this AO or in other applicable state and federal rules,
records shall be kept for a minimum of two (2) years. [R307-401]. [R307-150]
At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO
including associated air pollution control equipment in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
DAQE-AN0 l02l3000l-09
Page 3
1.6
1.7
II.A
11.A.l
II.A.2
11.A.3
II.A.4
II.A.5
11.A.6
11.A.7
11.B
II.B. l.a
II.B.l.b
operating and maintenance procedures are being used will be based on information available to
the Executive Secretary which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-40 l l
The owner/operator shall comply with R307-l50 Series. Inventories, Testing and Monitoring.
[R307-150]
The owner/operator shall comply with UAC R307-l07. General Requirements: Unavoidable
Breakdowns. [R307-l 07]
Section II: SPECIAL PROVISIONS
The approved installations shall consist of the following equipment:
Petroleum Pumping Station
Hanna Petroleum Pipeline Pumping Station
Equipment Leaks
Various Process Connection/Process Control Device Equipment Leaks
Comfort Heaters
Various comfort heating devices rated less than 5,000,000 Btu/hr -each (listed for
informational purposes only)
Tank 510
2,520,000 gallon External Floating Roof Storage Tank (1973)
Tank 520
2,520,000 gallon External Floating Roof Storage Tank (1972)
Tank 111
1,680,000 gallon Internal Floating Roof Storage Tank (1949)
Tank 530
2,520,000 gallon Internal Floating Roof Storage Tank (2009)
Requirements and Limitations
Visible emissions from any stationary point or fugitive emission source associated with the
source or with the control facilities shall not exceed 20% opacity. Opacity observations of
emissions from stationary sources shall be conducted in accordance with 40 CFR 60 . ' Appendix A, Method 9. [R307-401]
The following limits shall not be exceeded:
9,166,610 barrels of crude oil throughput per rolling 12-month period
1,896,540 barrels of black wax condensate mix throughput per rolling 12-month period
DAQE-AN0 l 02130001-09
Page 4
II.B.l.c
II.B.1.d
4,741,350 barrels of condensate throughput per rolling 12-month period
To determine compliance with a rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the twentieth day of each month using data from the previous l 2
months. Records of crude oil throughput shall be kept for all periods when the plant is in
operation. Crude oil throughput shall be determined by examination of company and/or
customer billing records. The records of crude oil throughput shall be kept on a monthly basis.
[R307-401]
Chevron USA Pipeline Company shall notify the Executive Secretary in writing when the
installation of the items appearing in the equipment list is complete and is operational. To
insure proper credit when notifying the Executive Secretary, send your correspondence to the
Executive Secretary, attn: Compliance Section. If the construction and/or installation is not
complete within 18 months from the date of this AO, the Executive Secretary shall be notified
· in writing on the status of the construction and/or installation. At that time, the Executive
Secretary shall require documentation of the continuous construction and/or installation of the
operation and may revoke the AO. [R307-401-18]
The owner/operator shall use propane or natural gas as fuel in the various comfort heating
devices. [R307-401]
Section III: APPLICABLE FEDERAL REQUIREMENTS
In addition to the requirements of this AO, all applicable provisions of the following federal programs
have been found to apply to this installation. This AO in no way releases the owner or operator from any
liability for compliance with all other applicable federal, state, and local regulations including UAC
R307.
NSPS (Part 60), Kb: VolatLiq/PetroStorageVessel 7/23/84
PERMIT HISTORY
This AO is based on the following documents:
Is Derived From Original NOi dated November 17, 2008
DAQE-AN0 I 02130001-09
Page 5
ACRONYMS
The following lists commonly used acronyms and their associated translations as they apply to this
document:
40CFR
AO
ATT
BACT
CAA
CAAA
CDS
CEM
CEMS
CFR
co
COM
DAQ
DAQE
EPA
HAP or HAPs
ITA
MACT
NAA
NAAQS
NESHAP
NOI
NO,
NSPS
NSR
PM10
PM2.s
PSD
R307
R307-401
S02
Title IV
Title V
UAC
UDAQ
voe
Title 40 of the Code of Federal Regulations
Approval Order
Attainment Area
Best Available Control Technology
Clean Air Act
Clean Air Act Amendments
Classification Data System (used by EPA to classify sources by size/type)
Continuous emissions monitor
Continuous emissions monitoring system
Code of Federal Regulations
Carbon monoxide
Continuous opacity monitor
Division of Air Quality (typically interchangeable with UDAQ)
This is a document tracking code for internal UDAQ use
Environmental Protection Agency
Hazardous air pollutant(s)
Intent to Approve
Maximum Achievable Control Technology
Nonattainment Area
National Ambient Air Quality Standards
National Emission Standards for Hazardous Air Pollutants
Notice of Intent
Oxides of nitrogen
New Source Performance Standard
New Source Review
Particulate matter less than 10 microns in size
Particulate matter less than 2.5 microns in size
Prevention of Significant Deterioration
Rules Series 307
Rules Series 307 -Section 401
Sulfur dioxide
Title IV of the Clean Air Act
Title V of the Clean Air Act
Utah Administrative Code
Utah Division of Air Quality (typicall y interchangeable with DAQ)
Volatile organic compounds
State of Utah
JON M. HUNTSMAN, JR.
Governor
GARY HERBERT
Lieutenam Governor
February 23, 2009
Jim Robbins
Department of
Environmental Quality
William J. Sinclair
Acting Executive Director
DIVISION OF AIR QUALITY
Cheryl Heying
Director
Chevron USA Pipeline Company
2875 S Decker Lake Dr, Ste 150
West Valley City, UT 84119
Dear Mr. Robbins:
f IL£ CO PY
DAQE-IN0 102130001-09
Re: Intent to Approve: Hanna Petrolum Pipeline Pumping Station, Duchesne County; CDS B;
Attainment Area, NSPS (Part 60)
Project Number: N010213-0001
The attached document is the Intent to Approve for the above-referenced project. The Intent to Approve
is subject to public review. Any comments received shall be considered before an Approval Order is
issued. The Division of Air Quality is authorized to charge a fee for reimbursement of the actual costs
incurred in the issuance of an Approval Order. An invoice will follow upon issuance of the final
Approv'al Order.
Future correspondence on this Intent to Approve should include the engineer's name as well as the DAQE
number as shown on the upper right-hand comer of this letter. The project engineer for this action is Tim
Dejulis, who may be reached at [phone].
Sincerely, "i .
Ty L. Howard, Manager
New Source Review Section
TLH:TDJ:kw
cc: TriCounty Health Department
150 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
STATE OF UTAH
Department of Environmental Quality
Division of Air Quality
INTENT TO APPROVE: Hanna Petrolum Pipeline Pumping
Station
Prepared By: Tim Dejulis, Engineer
Phone: [phone]
Email: [e-mail]
INTENT TO APPROVE NUMBER
DA QE-IN0102130001-09
Date: February 23, 2009
Hanna Pumping Station
Source Contact:
Mr. Jim Robbins Environmental Specialist
Phone: [phone]
Ty L. Howard, Manager
New Source Review Section
Utah Division of Air Quality
1.2
I.3
ABSTRACT
Ch~vron USA ~ipeline Company has requested permission to operate the Hanna pe_troleum pumping
stat10n as a stationary area source. The Hanna station receives crude oil, condensable hydrocarbons, and
black wax throughput from the company owned pipeline on its way to Salt Lake City. The Hanna station
serves as a buffer to pipeline operations allowing production to ebb and flow while at the same time
maintaining a consistent throughput within the pipeline.
Plant equipment includes four storage tanks ( one with 1,680,000 gallon capacity and three with 2,520,000
gallon capacity), electric pump motors, and various comfort heating equipment items rated less than
5,000,000 Btu/hr each.
The emissions, in tons per year, will be as follows:
VOC = 12.27, HAPs = 0.33
The NOI for the above-referenced project has been evaluated and has been found to be consistent with the
requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be
constructed, installed, established, or modified prior to the issuance of an AO by the Executive Secretary
of the Utah Air Quality Board.
A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the
intent to approve will be published in the Vernal Express on February 25, 2009. During the public
comment period the proposal and the evaluation of its impact on air quality will be available for the
public to review and provide comment. If anyone so requests a public hearing, it will be held in
accordance with UAC R307-401-7. The hearing will be held as close as practicable to the location of the
source. Any comments received during the public comment period and the hearing will be evaluated.
The proposed conditions of the AO may be changed as a result of the comments received.
Name of Permittee:
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
Permitted Location:
Hanna Pumping Station
40700 West 7000 North
Hanna, UT 84031
UTM coordinates:520,536 m Easting, 4,472,294 m Northing
SIC code:4612 (Crude Petroleum Pipelines)
Section I: GENERAL PROVISIONS
All definitions, terms, abbreviations, and references used in this AO conform to those used in the
UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to
those rules. [R307-l O l]
The limits set forth in this AO shall not be exceeded without prior: approval. [R307-401]
Modifications to the equipment or processes approved by this AO that could affect the emissions
covered by this AO must be reviewed and approved. [R307-401]
1.4
1.5
1.6
1.7
DAQE-IN0 102130001-09
Page 3
II.A
II.A. I
11.A.2
11.A.3
II.A.4
11.A.5
11.A.6
11.A.7
All records referenced in this AO or in other applicable rules, which are required to be kept by the
owner/operator, s.hall be made available to the Executive Secretary or Executive Secretary's
representative upon request, and the records shall include the two-year period prior to the date of the
request. Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401]. [R307-150]
At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to
the extent practicable, maintain and operate any equipment approved under this AO including
associated air pollution control equipment in a manner consistent with good air pollution control
practice for minimizing emissions. Determination of whether acceptable operating and maintenance
procedures are being used will be based on information available to the Executive Secretary which
may include, but is not limited to, monitoring results, opacity observations, review of operating and
maintenance procedures, and inspection of the source. All maintenance performed on equipment
authorized by this AO shall be recorded. [R307-401]
The owner/operator shall comply with R307-150 Series. Inventories, Testing and Monitoring.
[R307-150]
The owner/operator shall comply with UAC R307-107. General Requirements: Unavoidable
Breakdowns. [R307-107]
Section II: SPECIAL PROVISIONS
The approved installations shall consist of the following equipment:
Petroleum Pumping Station
Hanna Petroleum Pipeline Pumping Station
Equipment Leaks
Various Process Connection/Process Control Device Equipment Leaks
Comfort Heaters
Various c0mfort heating devices rated less than 5,000,000 Btu/hr -each (listed for
informational purposes only) ·
Tank 510
2,520,000 gallon External Floating Roof Storage Tank (1973)
Tank 520
2,520,000 gallon External Floating Roof Storage Tank (1972)
Tank 111
1,680,000 gallon Internal Floating Roof Storage Tank (1949)
Tank 530
2,520,000 gallon Internal Floating Roof Storage Tank (2009)
DAQE-IN0102130001-09
Page4
11.B
II.B .1.a
II.B.1.b
II.B.1.c
II.B.1.d
Requirements and Limitations
Visible emissions from any stationary point or fugitive emission source associated with the
source or with the control facilities shall not exceed 20% opacity. Opacity observations of
emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix
A, Method 9. [R307-40 l]
The following limits shall not be exceeded:
9,166,610 barrels of crude oil throughput per rolling 12-month period
1,896,540 barrels of black wax condensate mix throughput per rolling 12-month period
4,741,350 barrels of condensate throughput per rolling 12-month period
To determine compliance with a rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the twentieth day of each month using data from the previous 12
months. Records of crude oil throughput shall be kept for all periods when the plant is in
operation. Crude oil throughput shall be determined by examination of company and/or
customer billing records. The records of crude oil throughput shall be kept on a monthly basis.
[R307-401]
Chevron USA Pipeline Company shall notify the Executive Secretary in writing when the
installation of the items appearing in the equipment list is complete and is operational. To
insure proper credit when notifying the Executive Secretary, send your correspondence to the
Executive Secretary, attn: Compliance Section. if the construction and/or installation is not
complete within 18 months from the date of this AO, the Executive Secretary shall be notified
in writing on the status of the construction and/or installation. At that time, the Executive
Secretary shall require documentation of the continuous construction and/or installation of the
operation and may revoke the AO. [R307-401-18]
The owner/operator shall use propane or natural gas as fuel in the various comfort heating
devices.
[R307-401]
Section III: APPLICABLE FEDERAL REQUIREMENTS
In addition to the requirements of this AO, all applicable provisions of the following federal programs
have been found to apply to this installation. This AO in no way releases the owner or operator from any
liability for compliance with all other applicable federal, state, and local regulations including UAC
R307.
NSPS (Part 60), Kb: VolatLiq/PetroStorage Vessel 7 /23/84
PERMIT HISTORY
The final AO will be based on the following documents:
Is Derived From Original NOI dated November 17, 2008
DAQE-IN0102130001-09
Page 5
ACRONYMS
The following lists commonly used acronyms and their associated translations as they apply to this
document:
40CFR
AO
ATT
BACT
CAA
CAAA
CDS
CEM
CEMS
CFR
co
COM
DAQ
DAQE
EPA
HAPorHAPs
ITA
MACT
NAA
NAAQS
NESHAP
NOI
NO~
NSPS
NSR
PM10
PM2.s
PSD
R307
R307-401
S02
Title IV
Title V
UAC
UDAQ
voe
Title 40 of the Code of Federal Regulations
Approval Order
Attainment Area
Best Available Control Technology
Clean Air Act
Clean Air Act Amendments
Classification Data System (used by EPA to classify sources by size/type)
Con_tinuous emissions monitor
Continuous emissions monitoring system
Code of Federal Regulations
Carbon monoxide ·
Continuous opacity monitor
Division of Air Quality (typically interchangeable with UDAQ)
This is a document tracking code for internal UDAQ use
Environmental Protection Agency
Hazardous air pollutant(s)
Intent to Approve
Maximum Achievable Control Technology
Nonattainment Area
National Ambient Air Quality Standards
National Emission Standards for Hazardous Air Pollutants
Notice of Intent
Oxides of nitrogen
New Source Performance Standard
New Source Review
Particulate matter less than 10 microns in size
Particulate matter less than 2.5 microns in size
Prevention of Significant Deterioration
Rules Series 307
Rules Series 307 -Section 401
Sulfur dioxide
Title IV of the Clean Air Act
Title V of the Clean Air Act
Utah Administrative Code
Utah Division of Air Quality (typically interchangeable with DAQ)
Volatile organic compounds
State of Utah
JON M. HUNTSMAN, JR.
Governor
GARY HERBERT
Lieutenant Governor
Department of
Environmental Quality
William J. Sinclair
Acting Executive Director
DIVISION OF AIR QUALITY
Cheryl Heying
Director
FILE COPY
DAQE-NN0102130001-09
February 23, 2009
Vernal Express
Legal Advertising Dept.
60 East 100 North
Vernal, UT 84078-2122
RE: Legal Notice of Intent to Approve
This letter will confirm the authorization to publish the attached NOTICE in the Vernal Express on
February 25, 2009.
Please mail the invoice and affidavit of publication to the Utah State Department of Environmental
Quality, Division of Air Quality, P.O. Box 144820, Salt Lake City, Utah 84114-4820.
Sincerely,
~ rfi¼,y._
Kimberly Wilcox
Office Technician
Utah Division of Air Quality
Enclosure
cc: Uintah Basin Association of Governments
Duchesne County
150 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 .
Telephone [phone] • Fax (801 ) 536-4099 • T.D.D. (801 ) 536-4414
HllAllAI Aon 11tnh nf''I\J
DAQE-NNO 102130001-09
Page 2
NOTICE
A Notice oflntent for the following project submitted in accordance with §R307-401-1, Utah
Administrative Code (UAC), has been received for consideration by the Executive Secretary, Utah Air
Quality Board:
Company Name:
Location:
Project Description:
Chevron USA Pipeline Company
Chevron USA Pipeline Company: Hanna Pumping Station -40700 West 7000
North, Hanna, UT, Duchesne County
Chevron USA Pipeline Company has requested permission to operate the Hanna
petroleum pumping station as a stationary area source. The Hanna station receives
crude oil, condensable hydrocarbons, and black wax throughput from the company
owned pipeline on its way to Salt Lake City. The Hanna station serves as a buffer
to pipeline operations allowing production to ebb and flow while at the same time
maintaining a consistent throughput within the pipeline.
Plant equipment includes f~ur storage tanks (one with 1,680,000 gallon capacity
and three with 2,520,000 gallon capacity), electric pump motors, and various
comfort heating equipment items rated less than 5,000,000 Btu/hr each.
The emissions, in tons per year, will be as follows :
VOC = 12.27, HAPs = 0.33
The completed engineering evaluation and air quality impact analysis showed that the proposed project
meets the requirements of federal air quality regulations and the State air quality rules. The Executive
Secretary intends to issue an Approval Order pending a 30-day public comment period. The project
proposal, estimate of the effect on local air quality and draft Approval Order are available for public
inspection and comment at the Utah Division of Air Quality, 150 orth 1950 West, Salt Lake City, UT
84114-4820. Written comments received by the Division at this same address on or befor~ March 27, 2009
will be considered in making the final decision on the approval/disapproval of the proposed project. Email
comments will also be accepted at [e-mail]. If anyone so requests to the Executive Secretary at
the Division in writing within 15 days of publication of this notice, a hearing will be held in accordance
with R307-401-7, UAC. .
Date of Notice: February 25, 2009
'f NOTICE
A Notice of Intent
for the following
project • submitted
in accordance with
§R307-401-l, Utah
Administrative Code •
(UAC), has been
received for consider-
ation by the Executive
Secretary, Utah
· Air Quality Board:
Company Name:
Chevron USA Pipeline
Ccimpany Location:
Chevron USA Pipeline
Company: Hanna
Pumping Station
-40700 West 7000
North, Hanna, UT,
Duchesne County
Project Description:
Chevron USA
Pipeline Company has
requested permission
to operate the Hanna
petroleum pumping
station ~ a station-
ary area source. ·The
Hanna station receives
crude oil, condensable
hydrocarbons, and
black wax throughput
from the company
owned pipeline on
it way to Salt Lake
City. The Hanna sta-
tion serves as a buffer
to pipeline operations
allowing produc-
tion to ebb and flow
while at the same time
·maintaining a consis-
tent throughput within
the pipeline. Plant
equipment includes
four storage tanks
· (one with 1,680,000
gallon capacity and
three with 2,520,000
gallon capacity), elec-
tric pump motors,
and various comfort
heating equi{'ment
items rated Jess than
5,000,000 Btu/hr
each. The emissions,
in tons per y~ar, will
L;..... --.f:-11 ...... '";----· "1 70.{""" -
PROOF OF PUBLICATION
STATE OF UTAH, ·
County of Uintah
}S.S.
I, TONYA MUSE, being duly sworn, depose and say that I am the
Legals Manager of The Vernal Express, a weekly newspaper of
general circulation, published each week at Vernal, Utah, that the
notice attached hereto was published in said newspaper for I
publication(s), the first publication having been made on February
25, 2009 and the last on February 25 , 2009, that said notice was
published in the regular and entire issue of every number of the
paper during the period and times of publication, and the same was
published in the newspaper proper and not in a supplement.
109 lines. Publication fee, $81.75.
This page is not an billing statement or invoice, but a proof of
publication. Please make payment from billing invoice.
By-l--J-~~~M,~U(f-(~_ ~ LegalsManager
Subscribed and sworn to before me February 25, 2009.
UTAH DEPARTMENT OF
ENVIRONMENTAL QUALITY -·----..
1 MAR -2 2009 f
l ~--.. ----"' -..,.._ __ -.....f
DIVISION OF ~IA QUALITY
Ut= i:1.~ LUllUW:S. V VV -
12.27, HAPs = 0.33
The completed
engineering evalu-
ation an'd air qual-
ity impact analysis
showed that the pro-
posed proj.ect meets
the requirements of
federal air quality reg-
ulations and the State
air quality rules. The
Executive Secretary
intends to issue an
Approval Order pend-
ing a 30-day public
comment period.
The project proposal,
estimate of the effect
on local •air qual-
ity and draft Approval
.Order are available
for public inspec-
tion and comment
at the Utah Division
of Air Quality, 150
North 1950 West, Salt
Lake City, UT 84114-
4820. Wr-itten com-
ments received by the
Division at this same
address on or before
March 27, 2009 will
be considered in mak-
ing the final decision
on the approval/dis-
approval of the pro-
posed project. Email
comments will also
be accepted at tdeju-
[e-mail]. If any-
one so requests to the
Executive Secretary at
the Division in writ-
ing within 15 days
of publication of this
notice, a hearing will
be held in accordance
'Yith R307-401-7,
UAC. Date of Notice:
February 25, 2009.
Published in the
Vernal Express
February 25, 2009. PROOF OF PUBLICATION
STATE OF UTAH,
County of Uintah
I, TONYA MUSE, being duly sworn, dep
Legals Manager of The Vernal Express, a
general circulation, published each week
notice attached hereto was published in si
publication(s), the first publication havin~
25, 2009 and the last on February 25, 200
published in the regular and entire issue o
paper during the period and times of publi
published in the newspaper proper and no
1 nn. 1•
Chevron
NOTICE OF INTENT
HANNA STATION
RECEIVED
OCT 2 7 2008
Division of Air Quality
CHEVRON PIPE LINE COMPANY
October 20, 2008
Prepared by:
URS
756 East Winchester Street, Suite 400
Salt Lake City, UT 84107
URS Project: 24584986
Chevron Pipe Line Company
Hanna Station
The Hanna Station is a pipeline pump station along the pipeline that transports crude oil from the
Rangely Oil Field to Salt Lake City for refining. The station is owned and operated by Chevron
Pipe Line Company. It is located in Duchesne County at 40700 West 7000 North, Hanna, Utah
84031 (4,472,294 N, 520,536 E, UTM, NAD 83, Zone 12). The facility operates continuously,
24 hours per day, 365 days per year. The facility is not manned; but employees make daily visits
to operate and maintain the station.
The pipeline transports crude, condensate, and black wax. The Hanna Station consists of four ·
breakout tanks used to relieve surges or temporarily store crude from the pipeline for reinjection
and continued transportation by pipeline to Salt Lake City. In addition, there are two electric
pumps used to boost the pressure in the pipeline. The on-site evaporation pond is lined and is
used as a retention pond for stormwater runoffs; the drains for the pond are plugged. Stormwater
in the retention pond is not contaminated.
Sources of emission at the Hanna Station include the breakout tanks and piping components. The
anticipated throughput to the breakout tanks is 43 ,300 barrels per day (15,804,500 barrels per
year), consisting of 58% crude, 30% condensate, and 12% black wax condensate mixture.
Attached are the descriptions of the breakout tanks, report on Form 20.
Tank 111 -Internal floating roof tank, 40,000 barrels, installed 1949
Tank 510 -External floating roof tank, 60,000 barrels, installed 1973
Tank 520 -External floating roof tank, 60,000 barrels, installed 1972
Tank #TBD -Internal floating roof tank, 60,000 barrels, proposed installation in 2009.
Other equipment on site includes:
• Two 30,000 BTU propane space heaters
• Two 500-gallon pressurized propane tanks used to run the space heaters.
• One 300-gallon solvent tank for parts cleaning. Stoddard solvent does not include HAPs.
VOC emissions are approximately 3 pounds.
CHEVRON PIPE _NE CO.
HANNA STATION
1.0 BACKGROUND
BACT Analvsis
The Utah Division of Air Quality (DAQ) air permit regulations [UAC R307-401-5(2)(d) and
R307-401-8(1)(a)] require any new or modified source seeking an approval order must
consider the Best Available Control Technology (BACT). BACT is to be applied to new and
modified emission units and is to be .determined on a case-by-case basis, with consideration
given to energy impacts, technical feasibility, environmental impacts, and economic impacts.
This section presents a BACT analysis for the new and existing emission units that are part of
the Chevron Pipe Line Company Hanna Station.
For the Hanna Station, volatile organic compounds (VOCs) are the only pollutants emitted
into the atmosphere. For purposes of prevention of significant deterioration (PSD) analysis,
each project-affected source that emits VOCs must be evaluated to determine BACT. A
BACT analysis is being performed for each BACT emission applicable unit that is either
existing or will be installed at the facility and will have an increase of VOC emissions.
To complete a detailed BACT analysis, the United States Environmental Protection Agency
(U.S. EPA) top-down BACT methodology is used to analyze available options and then
select an appropriate control technology. To utilize the top-down approach, commercially
available control options for each applicable pollutant are identified. Technically infeasible
alternatives are then dismissed, and the remaining control options are analyzed and ranked
according to control effectiveness. To select a BACT option, the following items are
evaluated: energy impacts, environmental impacts, economic impacts, cost effectiveness, and
site-specific factors. The control technology selected provides the most stringent level of
control without causing adverse economic, energy, or environmental impacts. Generall y, the
cost effectiveness parameter is stated as either total or incremental annualized dollar cost per
ton of pollutant abated.
An extensive review of the U.S. EPA RACT/BACT/LAER Clearinghouse (RBLC) database
has been performed for similar sources to identify emission control strategies relevant to the
proposed project. An extensive review of the RBLC defined · the range of potentially
. applicable emission control applications.
For some Hanna Station sources, a strict top-down analysis is not necessary to identify
appropriate BACT. In these instances, accepted emission control technology alternatives are
identified. Of these, feasible alternatives may then be evaluated in comparison with accepted
BACT practices as described in the RBLC or in published BACT guidelines. In no case is
the recommended BACT less stringent than the controls required under New Source
Performance Standards (NSPS) and National Emission Standards for Hazardous Air
1
CHEVRON PIPE LINE ).
HANNA STATION BACT Analysis
Pollutants (NESHAP) regulations. The federal requirements are considered a "floor" for
BACT considerations.
For the Hanna Station, the BACT-applicable sources are listed below in Table 1.
Table 1
Hanna Station BACT-Applicable Sources
Source ID Source Description Estimated Increase (tpy)
PSD Pollutant -VOC
T-111 IFR Tank 0.94
T-510 EFR Tank 2.27
T-520 EFR Tank 1.81
T-TBD IFR Tank 1.38
Equipment Fugitives 5.62
Table 2 presents a summary of proposed BACT for the emission sources proposed to be
installed as part of the Hanna Station. Details of the BACT analysis are presented in the
remainder of this section.
Table 2
Summary of Proposed BACT
Source Description Pollutant
Internal Floating Roof voe Tanks
External Floating Roof voe Tanks
Process Fugitive voe
BACT = Best Available Control Technology
LDAR = Leak Detection and Repair
VOC = Volatile Organic Compound
2.0 TOP-DOWN BACT APPROACH
Most Feasible BACT Selected
• Internal Floating Roof
• Compliance with regulatory programs
• External Floating Roof
• Compliance with regulatory programs .
• Compliance with LDAR program .
• Leak definition more stringent than regulation .
BACT is defined in the Clean Air Act as "an emissions limit based on the maximum degree
of emissions reduction for each pollutant ... which the permitting authority determines, on a
case by case basis, taking in.to account energy, environmental, and economic impacts and
2
CHEVRON PIPE .NE CO.
HANNA STATION BACT Analvsis
other costs, is achievable for such facility through the application of production processes
and available methods, systems, and techniques ... ". Two key aspects of the definition are
worthy of notice:
• BAeT includes and, in fact, focuses on "production processes" along with add-on
controls.
• BAeT was intended to be a case-by-case evaluation, implying individual case
evaluations and deci sions, not rigid, pre-set guidelines.
The top-down BAeT approach starts with the most stringent (or top) technology that has
been applied to similar emissions units. A source of control technology information is the
RBLe database. The RBLe is an EPA-sponsored database that lists previously EPA-
approved BAeT determinations. The top control technology is either accepted as BAeT or
rejected based on technical or economic infeasibility. If the top control technology is
rejected as BAeT, the next most stringent control technology is either accepted as BAeT or
rejected. The top-down approach is continued until a control technology, which is found to
be both technically and economically feasible, is accepted as BAeT.
3.0 BACT APPLICABILITY
Each of the proposed units to be in stalled as part of the Hanna Station that generate any voe
emissions will require BAeT review. Existing emission units require a BAeT analysis as
well.
4.0 STORAGE TANKS
Four storage tanks (T-111, T-510, T-520 and T-TBD) produce voe emissions; therefore, an
analysis will be conducted to establish what constitutes BAeT. Resultant voe emissions
from storage tanks occur through two processes defined as working and breathing losses.
The existing storage tanks T-111, T-510, and T-520; and the proposed tank T-TBD are/will
be equipped with floating roofs as required by 40 eFR 60.112b(a), NSPS Subpart Kb.
Working loss emissions are mostly attributed to the loading and unloading of a tank, at which
time the hydrocarbon vapor located in the tank headspace is displaced. Working loss
emissions generally account for the large majority of emissions from storage tanks.
Breathing loss emissions occur from the cyclic diurnal temperature changes. Because the
equilibrium pressure of the vapor and liquid phases (vapor pressure) is a function of
3
CHEVRON PIPE LIN
HANNA STATION
J. ,r
BACT AnalVsis
temperature, this heating and cooling cycle allows for VOC displacement through the
expansion and contraction of the headspace.
4.1 Storage Tank voe BACT Anal ysis
The histori cal accepted VOC control practice for storage tanks consists of design meas ures to
minimize the hydrocarbon vapor space displacement.
4.1.1 Step 1 -Identify Potenti al Control Technologies
The first step in a BACT analysis is to identify all available control tec hnologies.
Review of Historical BA CT Determinations
The RBLC BACT databases contain numerous BACT determinations for the control of VOC
emission s from storage tanks. Review of the RBLC provides an indication of prior BACT
determin ation s for storage tanks. A summary of this review appears in Table A-1.
Ch evron Pipe Line also reviewed the BACT determinations for storage tanks at the proposed
Arizona Clean Fuels, LLC Greenfield refinery and the proposed Hyperion Greenfield
refinery in South Dakota as a means to supplement the RBLC search results. Some of these
determinations include:
• Fixed roof with a closed vent system and vapor capture system
• Internal floatin g roof wi th dual seals and inert gas blanketing
• External floating roof with dual rim seals
• Thermal oxidation
Option 1 -Internal fl oating roof tank with appropriate seal design
An internal floating roof tank incorporates a roof structure that floats on the liquid surface
exerting pressure on the vapor ph ase, thus decreasing the volume of vapor available to emit.
The floatin g roof would also uses an appropriate seal design to allow a minimal amount of
vapor from exiting as rim losses . In addition to a roof floating on the liquid surface an
additional fixed roof is al so constructed atop the storage tank fu rth er limiting the vapor
displacement to the atmosphere.
4
CHEVRON PIPE .NE CO.
HANNA STATION
Option 2 -External floating roof with appropriate seal design
BACT Analysis
This technology is similar to that listed in Option 1; however, there is no fixed roof atop the
floating roof to further minimize vapor displacement to the atmosphere.
Option 3 -Work Practices required by regulatory programs
Storage tanks are regulated under 40 eFR 60 (NSPS). These regulations require that the
facility comply with both vapor pressure and design requirements listed for storage tanks.
The requirements are specified in various ranges of vapor pressure and capacities.
Option 4 -Thermal Oxidation
Thermal oxidation combusts voe streams with a control efficiency of greater than 95%, and
can be used for control of any voe-containing stream, including storage tanks. Thermal
oxidation is used to process vented voe streams by using an incineration unit or flaring
device. While voes are destroyed in this process, other combustion emissions are created
and must be accounted for in the emission inventory for the refinery.
4.1.2 Step 2 -Eliminate Technically Infeasible Options
The second step in the BAeT analysis is to eliminate any technically infeasi ble control
technologies. Each control technology identified in Step 1 is technically feasible.
4.1.3 Step 3-Ranking of Remaining Control Technologies by Control Effectiveness
The third step in the BAeT analysis is to rank the remaining technically feasible control
technologies in order of control effectiveness. Table 3 shows that ranking.
5
CHEVRON PIPE LINE ).
HANNA STATION BACT Analvsis
Table 3
Ranking of Remaining Control Options for VOCs from Storage Tanks
Rank Control Type Control Efficiency
l Thermal Oxidation >95%
2a Internal floating roof Baseline
2b External floating roof Baseline
Uncontrolled emissions are not listed because industry standards prevent storing volatile
organic liquids in tanks without a roof.
4.1.4 Step 4-Evaluation of the Most Effective Controls
The fourth step in the BACT analysis is to evaluate the most effective control technologies
not eliminated due to technical infeasibility.
Thermal Oxidation
The feasibility of adding a thermal oxidation to the storage tanks was considered. Based on
standard cost estimation techniques and uncontrolled emissions, the cost of installing and
operating thermal oxidation would be approximately $106,000 -$256,000 per ton of VOC to
be removed per tank, which exceeds the typi cal cost thresholds used to verify the cost-
effectiveness of a control option ($5,000). The cost information and data used to support the
cost effectiveness determination is included in Table 4. This high cost is mostly attributed to
the low VOC emissions from each tank and the operational cost associated with the thermal
oxidizer. In addition to the high cost, thermal oxidizers do emit other criteria pollutants
resulting from combustion such as Ox, CO, PM10, etc. Due to the economic, energy, and
environmental impacts, the thermal oxidizer is being rejected as BACT.
6
CHEVRON PIPE _NE CO.
HANNA STATION BACT Analvsis
Table 4
Cost Estimate for Thermal Oxidizer
Service
T-111 T-510 T-520 T-TBD
CAPITAL COSTS:
Purchased Equipment (PE) 1 $ 400,000 s 400.000 s 400,000 s 400,000
Aux. Equipment 10% 0,:, of PC : $ .:io,ooo $ 40,000 $ 40.000 s 40,000
lnstrurncntntion 5'1/u 0i, nf PE l $ 20.000 $ 20,000 $ 20,000 $ 20,000
Freight 5'-ro .io of PE ! $ 20,000 $ 20.000 20,000 20,000
Sales Tax 6%, 0o of PE : s 2-l,000 $ 24,000 $ 24.000 $ 24,000
Purclrnsed Eauioment Cost (PEC) $ 504,000 $ 504,000 $ 504,000 $ 504,000
Direct Installation Costs
Foundations and support go, ' 0 0o (•f PE : s 40.320 s 40,320 $ 40,320 $ 40,320
Handling and erection 14'½, 0o ('f PE 1 $ 70,560 s 70.560 s 70.560 s 70,560
Electrical 4% 0o of PE : s 20,160 $ 20,160 s 20.160 $ 20,160
Piping 60% 00 t'f PE 1 s 302.400 $ 302,400 $ 302,400 $ 302.400
Ins ulation for ductwork 0.5~1u 011 of PE 1 s 2,520 $ 2.520 $ 2,520 s 2,520
Painting 0.111/;, 0·,, of P[; $ 504 s 504 s 504 s 504
Direct Installation Costs $ 436,464 $ 436.464 $ 436,464 $ 436,464
Direct Costs s 940,-164 $ 9-10.464 s 940,464 s 940,-16-l
Indirect Costs (Installation)
Engineering 6o'o 00 of PE: s 24.000 $ 24,000 s 24.000 s 24.000
Construction and field expenses IU°lc, 6o l'f P[l s 40.000 $ 40.000 s 40,000 s 40.000
Con tractor fees 2% %of PE: s 8.000 $ 8,000 s 8.000 $ 8,000
Start-up 1° 0 011 f•f PE~ $ 8.000 $ 8,000 s 8,000 $ 8,000
Contimicncics I01>1u "o of PE 1 s 40,000 s 40.000 s 40,000 $ 40,000
Indirect Costs $ 120,000 $ 120.000 s 120,000 $ 120,000
Total Capital Investment (TCI) s 1,060.464 s 1.060,464 s 1,060.464 $ I 060 464
OPERA TING COSTS 3:
Operating labor (0.5 hr / 8 hr shift), OP $ 25.00 per h0ur $ 13.688 $ 13,688 $ 13,688 $ 13.688
Supervisory labor. SL I 5°~ %ofOP s 2,053 $ 2.053 $ 2,053 $ 2,053
Maintcnru1ce labor (0.5 hr i 8 hr shift). ML $ 25.00 per hour s 13.688 $ 13,688 $ 13.688 $ 13 ,688
Maintenance Materials, i\,11\1 IOO"o 0oofM s 13,688 s 13,688 s 13,688 $ 13.688
Owrhead 60~. OO (If $ 25.869 s 25,869 $ 25.869 $ 25,869
UP-SL-ML-MM
Taxes, Jnsurnnec. and Admin. 411~ 0oofTCJ s 42,419 s -l~,419 s 42,419 s 42.4 19
Annual Onerating Costs $ 111,404 $ 111,404 s 111,404 $ ll I 404
U1pital Recover)' Factor (9.1 %, 20 yr life)
Annualized Total Capit al Investment' 0.1103 xTCI s 116.999 $ 116,999 $ 116,999 $ 116,999
Total Annual Costs s 228.403 $ 228,403 $ 228,403 $ 228,4!)3
Uncontrolled :VOC, tpy 0.9-10 2.270 1.810 1.380
95% VOC controlled, tons/yr 0.893 2.157 1.720 1.311
VOC Cost Effecth·cuess, S/1011 reduced s 255,770 $ 105,914 s 132,831 $ 174,220
Notes:
I) As obtained from discussions with in-house engineers.
2) Tvpical industry allowances as a pcrcent.1ge of purchased equipment (PE) costs: based on experience. engineering practices, discussions with potential
wndors, and as compared to the EPA-approved permit applications.
3) Costs based on experience. engineering practices. and the design for this pro_jcct.
4) Annual ized Total Capital Investment is estimated using the capital recovery factor for 20-yr life and 9.1 percent average interest: i.e., CRF =
(i( l+i)An)/((( l +i)An)-1 ).
7
CHEVRON PIPE LINE .J.
HANNA STATION
Floating Roof
BACT Analvsis
Installing a floating roof design is within the economic budget for the facility. It is more cost
effective to initially construct a floating roof tank than to convert a fixed roof tank to a
floating roof tank. The tanks at the Hanna Station tanks will have floating roofs as required
by 40 CFR 60.112b(a).
4.1.5 Step 5 -Selection of voe BACT for Storage Tanks
Because Chevron Pipe Line is interested in controlling emissions m a manner that is
environmentally effective, cost effective and in compliance with 40 CFR 60.112b(a),
Chevron proposes that the installation and operation of floating roof tanks subject to NSPS
requirements be considered BACT for VOC for the Storage Tanks. Tanks T-520 and T-510
are equipped with external floating roof tanks, and Tanks T-111 and T-TBD is/will be
equipped with internal floating roof tanks.
4.1.6 Practically Enforceable BACT for Storage Tanks
Development of emission limit to reflect selected control technology
VOC emissions from the Storage Tanks were calculated using the EPA TANKS 4.09d
software. The estimated VOC emissions associated with storage tanks T-111, T-520, T-510,
and T-TBD are 0.41, 1.39, 1.53, and 0.58 tons VOC per year respectively. This emissions
estimate is based upon the current/expected design and emissions calculations from EPA
TANKS 4.09d. The facility will ensure th at the selected BACT is properly installed,
operated, and the selected work practice standards are properly implemented.
Compliance Monitoring
The facility will comply with applicable NSPS Subpart Kb requirements for the storage
tanks. All monitoring, recordkeeping, and reporting will be done in compliance with NSPS
requirements.
5.0 PROCESS FUGITIVES
The Hanna Station uses man y piping components to distribute the liquid materials (mostly
crude oil). between tanks and pipeline. These piping components are potential sources of
8
CHEVRON PIPE _NE CO.
HANNA STATION BACT Analvsis
VOC effi1ss10ns due to leaking equipment. VOC emissions from those components are
mostly related to potential leakage from valves, flanges, and pump seals.
It is important to Chevron that these piping components are effectively monitored to decrease
emissions as much as possible. The piping components carry products which contain VOCs
that will increase emissions if the component leaks. Therefore, a Chevron has employed a
Leak Detection and Repair (LDAR) Program to minimize leaks.
5.1 Fugitive VOC BACT Analysis
Common strategies for controlling VOC em1ss10ns from equipment leaks are based on
LDAR work practices rather than by the traditional emission limits and control devices. The
LDAR program currently implemented at the Hanna Station incorporates a vigorous
monitoring schedule involving visual inspection (via olfactory inspections) to . monitor and
control emissions from piping components. Chevron Pipe Line proposes to comply with the
most stringent requirements for LDAR.
5.1.1 Step 1 -Identify Potential Control Technologies
The first step in a BACT analysis is to identify all available control technologies.
Review of Historical BACT Determinations
The RBLC database review provides an indication of historical BACT determinations for
fugitive emissions. The RBLC database contains numerous BACT determinations for the
control of VOC fugitive emissions. A summary of this review can be found in Table B-1.
As demonstrated in a review of the RBLC, the primary control strategy across the board for
fugitive VOC emissions is an effective LDAR program. This is true for a facility with
fugitive emission limits both on the high and low ends. The requirements for such programs
are defined in the Federal regulations.
Chevron Pipe Line also reviewed the BACT determinations for equipment leaks at the
proposed Arizona Clean Fuels, LLC Greenfield Refinery and the proposed Hyperion .
Greenfield Refinery in South Dakota as a means to supplement the RBLC search results.
Some of these determinations include:
9
CHEVRON PIPE LINE J.
HANNA sTATioN BACTAnalVsis
· • Adopt more-stringent leak detection definitions consistent with TRNCC 28 MID
emission reduction option.
• Limited implementation of seal-less magnetic drive pumps and bellows-seal valves.
• Implement a LDAR program consistent with 40 CFR 63 -Subparts II and CC.
Option 1 -Implementation of applicable regulatory programs
The RBLC analysis demonstrates that the p1imary control strategy for control of fugitive
VOC emissions is an effective LDAR program. An effective LDAR program includes a
suitable definition of a "leaky" component threshold concentration and a detailed strategy for
repairing leaks once they have been identified. For the Hanna Station, NESHAP -Subpart R
is applicable. NESHAP -Subpart R does not specify a leak definition since the only
monitoring that is required is that performed by visual inspections. The Hanna Station
proposes to comply with NESHAP -Subpart R. A summary of applicable regulatory
_requirements and proposed BACT can be found in Table 5.
10
CHEVRON PIPE _NE CO.
HANNA sTATioN BACT Analvsis
Table 5
Summary of Proposed BACT and Applicable Equipment Leak Requirements
Component Proposed NESHAP
BACT Subpart R
Valves-Light Liquid No visual No visual
leaks leaks
Valves-Heavy Liquid No visual No visual
leaks leaks
Valves-Gas No visual No visual
leaks leaks
Pumps-Light Liquid No visual No visual
leaks leaks
Pumps-Heavy Liq uid No visual No visual
leaks leaks
Pressure Relief Valve-No visual No visual
Gas leaks leaks
Pressure Relief Valve-No visual No visual
Liquid leaks leaks
Light L iquid No visual No visual
Connectors leaks leaks
VOC Compressors No visual No visual
leaks leaks
Closed Vent Systems No visual No visual
leaks leaks
Option 2 -Implementation of enhanced regulatory program
As di scussed in Option 1, Hanna Station will comply with the applicable requirements of
NESHAP -Subpart R. The enh ancement of applicable regulatory programs will not be
necessary since there are no other applicable equipment leak provisions applicable to the
Hanna Station. Furthermore, the facility transpo1ts/stores crude oil and petroleum refinery
standards to not apply to the facility.
5.1.2 Step 2 -Eliminate Technically Infeasible Options
The second step in the BACT analysis is to eliminate any technically infeasible. control
technologies. The implementation of applicable regulatory programs as described in Step l
is technically feasible.
11
CHEVRON PIPE LINE J.
HANNA STATION BACT Analysis
5.1.3 Step 3 -Ranking of Remain ing Control Technologies by Control Effectiveness
The third step in the BACT analysis is to rank the remaining technically infeasible control
tec hnologies in order of control effectiveness. The most effective of the identified control
tec hnologies is a combination of the identified options. Specifically, thi s includes an LDAR
program with work practices relative to NESHAP -Subpart R.
5.1.4 Step 4 -Evaluation of the Most Effective Controls
The fourth step in the BACT analysis is to evaluate the most effective control technologies
not eliminated due to technical infeas ibility. The most effective identified control strategy
for fugitive VOC emissions is proposed as BACT. This system will not result in any adverse
energy or environmental impacts . Accordingly, no evaluation of alternative control options
is warranted.
5.1.5 Step 5 -Selection of voe BACT fo r Fugitive Emissions
Chevron proposes that the implementation of an LDAR program m compliance with
NESHAP -Subpart R be considered BACT for fugitive emissions of VOC. The LDAR
program, as identified in the five step process, will reduce emissions through determination
of leaks identified by visual inspections. Compliance with NESHAP -Subpart R will reduce
emissions of any regulated pollutant within the transport streams.
Practically Enforceable BACT for Fugitive Emissions
Development of Emission Limit to Reflect Selected Control Technology
VOC emissions from the fu gitive emission sources were calculated using emission factors
taken from the Protocol for Equipment Leak Emission Estimates, EPA-453/R-95-017, Table
2-2 and Refinery Average Emission Factors and the Equipment Leaks Fugitives guidance
document from the TCEQ (dated November 1995).
The following regulations from 40 CFR 60 (NSPS), and 40 CFR 63 (NESHAP) were
reviewed in relation to fugiti ve emissions: .
• NESHAP Subpart R -ational Emission Standards for Gasoline Distribution
Facilities (Bulk Gasoline Terminals & Pipeline Breakout Stations)
12
CHEVRON PIPE _NE CO.
HANNA sTATioN BACTAnalvsis
• NESHAP Subpart CC (not applicable) -National Emission Standards for Hazardous
Air Pollutants from Petroleum Refineries
• NSPS Subpart GGG (not applicable) -Standards of Performance for Equipment
Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After January 4, 1983, and on or Before November 7, 2006
• NSPS Subpart GGGa (not applicable) -Standards of Performance for Equipment
Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After November 7, 2006
• NSPS Subpart VV (not applicable) -Standards of Performance for Equipment Leaks
of VOC in the Synthetic Organic Chemicals Manufacturing Industry for Which
Construction, Reconstruction, or Modification Commenced After January 5, 1981 ,
and on or Before November 7, 2006
• NSPS Subpart VVa (not applicable) -Standards of Performance for Equipment
Leaks of VOC in the Synthetic Organic Chemicals Manufacturing Industry for Which
Construction, Reconstruction, or Modification Commenced After November 7, 2006
. Of the regulations reviewed, it was determined that the Hanna Station is only subject to
NESHAP -Subpart R. Therefore, the Hanna Station must comply with the requirements of
an LDAl} program structured according to the requirements of NESHAP -Subpart R.
LDAR program compliance is enforceable through evaluation of LDAR monitoring and
repair documentation. Visual inspections will be used to effectively identify leaks, and
LDAR documentation will be maintained through LEAKDAS. LDAR program compliance
will be continuous.
Compliance Monitoring
The Chevron Pipe Line Hanna Station is proposing compliance with the enhanced LDAR
program as specified in Table 5 of this permit application. The facility has implemented an
LDAR Program to assure compliance with NESHAP requirements for the facility. All
monitoring, recordkeeping, and reporting will be done in compliance with the applicable
equipment leak requirements.
13
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
FACILITY PERMIT THRU THRU EMIS EMIS
FACILITY NAME PROCESS NAME PUT CONTROL DESCRIPTION LIMIT LIMITl STATE DATE PUT UNIT 1 UNIT
FUEL OIL KENAI REFINERY AK 3/2 1/2000 NONE INDICATED STORAGE TANKS
FUEL OIL KENAI REFINERY AK 3/2 1/2000 NONE INDICATED STORAGE TANKS
THE EMISSIONS FROM GROUP A
STORAGE TANKS MUST BE
COLLECTED BY A VAPOR
COMPRESSION SYSTEM AND
ARIZONA CLEAN AZ 4/14/2005 GROUP A ROUTED TO THE REFINERY
FUELS YUMA STORAGE TANKS FUEL GAS SYSTEM. NO
EMISSIONS ARE PERMITTED TO
BE RELEASED INTO THE AIR
EXCEPT FOR EQUIPMENT
LEAKS.
THE EMISSIONS FROM GROUP A
STORAGE TANKS MUST BE
COLLECTED BY A VAPOR
COMPRESSION SYSTEM AND
ARIZONA CLEAN AZ 4/14/2005 GROUP A ROUTED TO THE REFINERY
FUELS YUMA STORAGE TANKS FUEL GAS SYSTEM . NO
EMISSIONS ARE PERMITTED TO
BE RELEASED INTO THE AIR
EXCEPT FOR EQU IPMENT
LEAKS.
THE TANKS ARE REQUIRED TO
ARIZONA CLEAN AZ 4/14/2005 GROUPD BE UNDER PRESSURE SO THAT
FUELS YUMA STORAGE TANKS NO EM ISSIONS ARE EM ITTED TO
THE ATMOSPHERE.
FIXED ROOF TANK WITH
ARIZONA CLEAN AZ 4/14/2005 SOUR WATER INTERNAL FLOATING ROOF.
FUELS YUMA TANK HEAD SPACE ROUTED TO A
CARBON ADSORPTION SYSTEM.
BACT Analvsis
POLLUTANT COMPLIANCE NOTES
KEEP RECORDS READILY AVAILABLE
SHOWING THE DlMENSIONS AND
CAPACITIES OF THE STORAGE VESSELS.
KEEP RECORDS READILY AVAILABLE' '-
SHOWING THE DIMENSIONS AND
CAPACITIES OF THE STORAGE VESSELl'o' ~
THERE IS NO NUMERICAL EMISSIONS
LIMIT FOR GROUP A TANKS SINCE THE
EM ISSIONS MUST BE COLLECTED AND
NOT EMITTED INTO THE ATMOSPHERE.
THERE IS NO NUMERICAL EMISSIONS
LIMIT FOR GROUP A TANKS SINCE THE
EMISSIONS MUST BE COLLECTED AND
NOT EM ITTED INTO THE ATMOSPHERE.
I -THE TANKS ARE REQUIRED TO BE
UNDER PRESSURE SO THAT NO
EMISSIONS ARE EMITTED TO THE
ATMOSPHERE.
FIXED ROOF TANK WITH INTERNAL
FLOATING ROOF. HEAD SPACE ROUTED
TO A CARBON ADSORPTION SYSTEM .
~
14
Utah DivL Jn of Air Quality
New Source Review Section
Form 1
General Information
Application for: 0 Initial Approval Order
Date 10/20/2008
□ Approval Order Modification
AN APPROVAL ORDER MUST BE ISSUED BEFORE ANY CONSTRUCTION OR INSTALLATION CAN BEGIN. This is not a
stand alone document. Please refer to the Permit Application Instructions for specific details required to complete the
application. Please print or type all information requested. All information requested must be completed and submitted before
an engineering review can be initiated. If you have any questions, contact the Division of Air Quality at [phone] and ask
to speak with a New Source Review Engineer. Written inquiries may be addressed to: Division of Air Quality, New Source
Review Section, P.O. Box 144820, Salt Lake City, Utah 84114-4820.
Applicable base fee for engineering review and filing fee must be submitted with the application.
General Owner and Facility Information
1. Company name and address: 2. Company contact for environmental matters:
Chevron Pipe Line Company Jim Robbins
2875 South Decker Lake Drive, Suite 150 Environmental Specialist
West Valley City, UT 84119 Phone No.: [phone]
Phone No.: [phone] Fax No.: [phone]
Fax No.: [phone]
3. Facility name and address (if different from above): 4. Owners name and address:
Hanna Station N/A
40700 West 7000 North
Hanna, UT 84031
Phone no .: None Phone no.: ( )
Fax no.: None Fax no.: ( )
5. County where the facility is located in: 6. Latitude & longitude, and/or UTM coordinates of plant:
·Duchesne 4,472,294 N, 520,536 E
UTM, NAD 83, Zone 12 (meters)
7. Directions to plant or Installation (street address and/or directions to site) (include U.S. Coast and Geodetic Survey
map if necessary):
40700 West 7000 North
Hanna, UT 84031
8. Identify any current Approval Order(s): N/A
AO# Date AO# Date
AO# Date AO# Date
AO# Date AO# Date
9. If request for modification, permit# to be modified: DAQE# N/A DATED: I I
10. Type of business at this facility: Crude pipeline pump station
11 . Total company employees greater than 100? 12. Standard Industrial Classification Code
4612 Crude petroleum pipelines
□ Yes 0 No
Page 1 of 4
Approval Order Application
Form 1 (Continued)
13. Application for:
D New construction 0 Modification
0 Existing equipment operating without permit □ Permanent site for Portable Approval Order
□ Change of permit condition □ Change of location
14. For new construction or modification, enter estimated start date: Jan 2008 Estimated completion date: Sep 2009
15. For change of permittee, location or condition, enter 16. For existing equipment in operation without prior permit,
date of occurrence: N/A enter initial operation date: 1949
17. Has facility been modified or the capacity increased since November 29, 1969: □ Yes 0 No
Process Information
18. Site plan of facility (Attach as Appendix A): See Appendix A.
19. Flow diagram of entire process to include flow rates and other applicable information (Attach as Appendix B):
See Appendix B.
20. Detailed writt_en process and equipment description. (Attach as Appendix C):
Description must include:
Process/Equip specific form(s) identified in the instructions
Fuels and their use Equipment used in process Description of product(s)
Raw materials used Operation schedules Description of changes to process (if applicable)
Production rates (including daily/seasonal variances)
See Appendix C. Includes Form 20 -Organic Liquid Storage Tank
21. Does this application contain justifiable confidential data? o Yes 0No
Emissions Information
22. Complete and attach Form 1 d, Emissions Information See Appendix D.
Include Material Safety Data Sheets for all chemicals or compounds that may be emitted to the atmosphere.
23. Identify on the site plan (see #18 above) all emissions points, building dimensions, stack parameters, etc.
See Appendix A.
Air Pollution Control Equipment Information
24. List all air pollution control equipment and include equipment specific forms identified in the instructions.
J\.U,--L ,....., /\..-.. n No air pollution control equipment. -~ _,, -·
25. List and describe all compliance monitoring devices and/or activities (such as CEM, pressure gages). Attach as /\----rl,~ C No compliance monitoring de.vices. -·
26. Submit modelinq for the project if required. See attached instructions. Modeling not required.
27. Attach as Appendix f: your proposal of what air pollution control devices, if any, or operating practices represents Best
Available Control Technology. Discuss and evaluate all air pollution control tech nologies relevant to your situation or
process. See Appendix E.
28. I hereby certify that the information and data submitted in and with this application is completely true, accurate and
complete, based on reasonable inquiry made by me and to the best of my knowledge and belief.
Siqnature: Title: Midcontinent Operational Manager, Northwest
29. Brad Rosewood 30. Telephone Number: 30. Date: October 27, 2008
Name (Type or print) [phone]
Page 2 of 4
Approval Order Application
Form 1 Instructions
1. Identify the name, address, phone number, and fax number of the legal entity that operates the equipment.
2. Identify the person who is to be contacted regarding this application; also include the phone number and fax number
of this person. ·
3. Identify the address where the equipment will be located.
4. If you are not the owner of the equipment under this application, enter the name, address, phone number, and fax
number of the owner.
5. Identify in what county the facility is located. If this is portable equipment, state in what county the first location is.
6. Indicate the technical location of the facility so that it can be located on a map for modeling and inventory purposes.
The location can be read from a 7.5· map.
7. Indicate the geographical location or address of facility and directions to site if needed for remote locations. For
example, Go five miles south on highway 1, turn left at farmhouse, go 1.5 miles.
8. List any valid Approval Orders (AO) which are for equipment at this site.
9. Indicate previous AO number (if any) and date for AO modification.
10. State the type of business you conduct at this facility.
11 . Indicate if the total number of people employed by your company is over 100 people.
12. Using the provided list of business codes (page 8), enter the code which best describes your business activity at this
facility.
13. Check all applicable boxes
New Construction: new equipment which has not yet been constructed and requires a permit to construct.
Existing Equipment Operating Without Permit: equipment which has been in operation without a prior permit
issued by the state.
Change of permit condition: permitted equipment which will be operated contrary to permit conditions.
Modification: existing equipment which.is physically altered by the removal, addition, or non-identical replacement
of parts.
Permanent site: equipment will be located continuously at one site for more than 180 days.
Change of location: permitted equipment which will be transferred from one property to another.
14. Enter the start date and the completion date of any new installation, construction, or modification.
15. For cases in this category, enter the future date when the change is anticipated.
16. For this category of equipment, enter the date when this equipment was first operated.
17. This is for equipment that was operated before November 29, 1969. Indicate whether the facility has been modified
or increased capacity since that date.
18. Attach as Appendix A to the application a site plan in sufficient detail to identify: general location of site, buildings,
roads, process equipment, emission points, and site characteristics that may effect plume dispersion.
19. Attach as Appendix B to the application a flow diagram which illustrates the entire process from introduction of raw
materials to the emission of exhaust to the atmosphere and includes at least the following: generating equipment,
process equipment, control equipment, monitoring devices, duct work, hoods, fans , stacks, flow rates/direction,
gauges, etc.
20. Attach as Appendix C to the application a narrative description of the process and equipment to be permitted.
Essentially include a narrative of the flow chart above. The description must include equipment or process specific
forms as appropriate. The attached general supplemental process form (Form 2) must be filled out by all sources.
Please mark which forms below apply to th is project. Forms available upon request are as follows:
Form 11 Internal Combustion Engines
Form 12 Incinerators
Form 13 Spray Booths
Form 14 Concrete Batch Plants
Form 15 Rock Crushing and Screening
Form 16 Soil/groundwater Remediation
Form 17 Diesel Powered Standby Generator
Form 18 Portable Hot Mix Drum Asphalt Plants
Form 19 Fuel Burning Equipment (Boilers, Heaters, Steam Generators)
Form 20 Organic Liquid Storage Tank
Form 21 Solvent Metal Cleaning (degreasers)
Form 22 Combustion Turbines
21 . To claim confidentiality on information submitted with this application, check "yes". Be sure that all submitted
information which you wish kept confidential is clearly marked as such. Also state the reason(s) for claiming
confidentiality per 40CFR2.208. Examples of acceptable reasons are_ trade secrets and production data. Note that
information on emissions and permits cannot be confidential.
3 of 4
New Source Review Application
Form 1 Instructions (Continued)
22. Attach a completed Form 1 d, Emissions Information. Provide all MSD Sheets for all chemicals used.
23. List emission points and parameters on the site plan (#14 above).
24. Attach as Appendix D to the application a list of all air pollution control equipment. Must include form(s) as
appropriate. Please mark which forms apply to this project. Forms available upon request are as follows:
Form 3
Form 4
Form 5
Form 6
Form 7
Form 8
Form 9
Form 10
Afterburners
Flares
Adsorption Unit
Cyclone
Condenser
Electrical Precipitators
Scrubber
Fabric Filter
25. Attach as Appendix E to the application a list with description of all compliance monitoring devices and/or activities.
Include such things as make, model, type, size, capability, accuracy, calibration frequency, etc. for the devices and
monitoring frequency, outline of training program, level of certification required of inspectors, etc. for monitoring
activities.
26. Dispersion modeling will be required under two circumstances:
1. if the Executive Secretary determines that modeling is to be performed.
2. if the proposed emissions are in the range of values given in given in Table 1.
This requirement holds for new as well as modified sources. For modified sources, the values in Table 1. denote
emission increases. If the emission values are greater than values in Table 1, higher level modeling will be required.
Call the Planning Section at [phone] for additional information. The meteorological data to be used in the
modeling must be submitted to the Executive Secretary for review and approval before they are used in the
dispersion modeling exercise.
Table 1. Criteria For Screen Modeling (tons/year)
S02
NOx
PM10 fugitive
PM,0 non-fugitive
CO*
HAP**
lead
40
40
5
15
100/250
varies
0.6
100 tons if one of the 28 source categories in UAC R307-1-3.6.5.B; 250 tons if not
Contact the Division of Air Quality Modeling Section.
27. For a description of a proper BACT proposal, see Form 1 b.
28. Signature of authorized company agent.
29. Name of signing party.
30. Telephone number of signing party.
31 . Date of application.
ADDITIONAL INFORMATION MAY BE REQUIRED FOR SOME APPLICATIONS. If so, the reviewing engineer will
contact the individual listed in question number 2.
U:\aq\ENGINEER\GENERIC\Form01.doc
Revised 5/10/06
4 of 4
. ' UtaH . vision of Air Quality
New Source Review Section
Form 1d
Emissions Information
Cc. any Chevron Pipe Line Co.
Site/Source Hanna Station
Date 10/20/2008
Please print neatly or type all information requested. All information must be truthful, accurate and complete before
we can process your application. If you have any questions, call [phone] and ask to speak with a New
Source Review engineer. Written inquiries may be addressed to: Division of Air Quality, NSR Section, P.O. Box
144820, Salt Lake City, Utah 84114-4820.
Table 1. Proposed Emissions
Pollutant Permitted Emissions Emissions Increases Proposed Emissions
(tons/year) (tons/year) (tons/year)
PM10
SO2
NOx
co
'
voe 12
Hazardous 0.3 Air Pollutants (total}
Hazardous Air
Pollutants (list
individually) (attach
additional sheet if
needed)
2,2,4-
Trimethylpentane 0.01
(isooctane)
Benzene 0.02
Biphenyl 0.00
Cresol (-m) 0.00
Ethylbenzene 0.01
Hexane (-n) 0.19
lsopropyl benzene 0,00 (cumene)
Naphthalene 0.01
Toluene 0.04
Xylenes (mixed 0.05 isomers)
other pollutants (list)
(attach additional
sheet if needed)
Page l of 4
Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
Table 2. Controlled and Uncontrolled Emissions
Pollutant Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year)
PM1o
S02
NOx
co
voe 12
Hazardous Air Pollutants (total) 0.3
Hazardous Air Pollutants (list
individually) (attach additional sheet if
needed)
2,2,4-Trimethylpentane (isooctane) 0.01
Benzene 0.02
Biphenyl 0.00
Cresol (-m) 0.00
Ethyl benzene 0.01
Hexane (-n) 0.19
lsopropyl benzene (cumene) 0.00
Naphthalene 0.01
Toluene 0.04
Xylenes (mixed isomers) 0.05
other pollutants (list) (attach
additional sheet if needed)
.
Page 2 of 4
< L Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
Table 3. Hourly HAP Emissions
Hazardous Air Pollutants (list individually) Maximum emission rate (lbs/hour)
2,2,4-Trimethylpentane (isooctane) 0.0019
Benzene 0.0053
Biphenyl 0.0005
Cresol (-m) 0.0008
Ethyl benzene 0.0026
Hexane (-n) 0.0443
lsopropyl benzene (cumene) 0.0007
Naphthalene 0.0012
Toluene 0.0086
Xylenes (mixed isomers) 0.0125
Page 3 of 4
Table 1.
Table 2.
Table 3.
Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
Instructions
Fill out the table. Attach additional sheets if necessary. Provide potential emissions from your
entire facility in units of tons per year, expressed to at least two decimal places. Emissions of
individual Hazardous Air Pollutants may require more precision; contact a New Source Review
Engineer. If you do not now have an Approval Order and you are applying for your first
Approval Order, the emissions in "Existing Emissions" column will be zero and the "Emissions
Increases" will be equal to the "Proposed "Emissions. If you do have an Approval Order, the
emissions in the "Existing Emissions" column will be the emissions listed in your Approval
Order. All emissions should be those emissions occuring after any air pollution control devices.
Provide emissions that would result if you operated 24 hours per day, 8760 hours per year,
unless you are also proposing operating hour limits. If you are proposing operating hour limits,
state what these 1-imits are and provide emissions based on these limits. Provide emissions that
would result from your potential production or potential raw material consumption, unless you
are also proposing production or raw material consumption limits. If you are proposing
production or raw material consumption limits, state what these limits are and provide emissions
based on these limits. Attach additional sheets with detailed calculations or stack testing
information showing how all of the above emission numbers were determined.
Fill out the table. Attach additional sheets if necessary. Provide potential emissions from your
entire facility in units of tons per year, expressed to at least two decimal places. Emissions of
individual Hazardous Air Pollutants may requ ire more precision; contact a New Source Review
Engineer. The Hazardous Air Pollutants should be the same Hazardous Air Pollutants listed in
Table 1. The emissions in the "Controlled Emissions" column shoud be those emissions
occuring after any air pollution control devices. The emissions in the "Uncontrolled Emissions"
should be those emissions occuring before any air pollution control devices (in other words,
emissions that would result if you did not have any air pollution control devices at all. Provide
emissions that would result if you operated 24 hours per day, 8760 hours per year, unless you
are also proposing operating hour limits. If you are proposing operating hour limits, state what
these limits are and provide emissions based on these limits. Provide emissions that would
result from your potential production or potential raw material consumption, unless you are also
proposing production or raw material consumption limits. If you are proposing production or raw
material consumption limits, state what these limits are and provide emissions based on these
limits. Attach additional sheets with detailed calculations or stack testing information
showing how all of the above emission numbers were determined.
List all Hazardous Air Po llutants emitted by your facil ity. They should be the same Hazardous Air
Pollutants listed in tables 1 and 2. For each HAP provide its maximum emission rate in units of
pounds per hour. The emission rates should be those rates occuring after any air pollution
control devices. Attach additional sheets with detailed calculations or stack testing
information showing how all of the above emission numbers were determined.
Depending on other conditions unique to each facility, additional emissions information may be required.
f:\aq\engineer\generic\ 1 d_emisn.frm
Revised 1 /23/03
Page 4 of 4
Utah Division of Air Quality
New Source Review Section
Site/Source.:...: --=-H=-=a:..:..:n:..:..:n=a.,_, =U-=-T ____ _
Form 20 Date: ___ _,1c,::0!....:/1c,::5"""/2=-=0=0=8 ___ _
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: GATX 2. ldentific9tion number: Tank 520
3. Installation date: 1972 4. Volume: 2,520,000 gallons
5. Inside tank diameter: 95 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 79,654,680 gallons per year 12. Turnovers/yearly 31.6 Monthly Weekly
13. Average liquid height (feet): 48 14. Access hatch: l;zJ Yes □ No Number 1
15. Type of Seals: 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well Iii Yes o No Number_1_
Ill Mechanical shoe Gauge hatch/
□ Resilient filled sample well 0Yes □ No Number_1_
□ Liquid filled Roof drains □ Yes o No Number --□ Vapor mounted Rim vents 1;zJYes o No Number 1
□ Liquid mounted Vacuum break @Yes □ No Number 1
□ Flexible wiper Roof leg lil Yes o No Number___1L
b. Secondary seal: Ladder well □ Yes □ No Number --Type: Wi~er, rim-mounted Column well □ Yes o No Number --
Other: 1 unslotted guide-~ole well
17. Shell Characteristics: 18. Type of Construction:
Condition: Good □ Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction: Welded □ Internal Floating Roof
Roof Type: Pontoon 0 External Floating Roof
Deck Construction: Welded □ Other (please specify)
Deck Fitting Category: T~~ical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket □ Venting □ Carbon Adsorption □ Thermal Oxidation □ Other:
20. Single Liquid Information
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. -Avg . Temperature:
Vapor Pressure: ,___ Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Form
21.
Chemical Name: -
-Organic Liquid Storage Tank
(Continued)
Chemical Components Information
Chemical Name: -See TANKS Percent of Total Liquid Weight:_ printout in -Percent of Total Liquid Weight:
Molecular Weight: Appendix D. -Molecular Weight:
Avg . Liquid Temperature: -Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM 10 Lbs/hr __ Tons/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/hr __ Tons/yr voe 237 Lbs/hr 1.81 Tons/yr
HAPs 8.18 Lbs/hr (speciate) 0.06 Tons/yr (speciate)
Submit calculations as an appen di x. Provide manufacturer's Material Safety Data Sh eets for products being stored.
· See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Qivision of Air Quality (DAO) at [phone] if you have problems or questions in filling out this form .
Ask to speak with a New Source Review engineer. We will be glad to help!
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification nu mber that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of th e liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liq uid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) fo r fixed roof tanks
Tank construction , welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chem icals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Site/Source.:...: --=-H=a:..:..;n=n=a.,_1 =U-=-T ____ _
Form 20 Date: ___ ..:....:10:!../1.:...:5=/2=0=0=8 ___ _
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: GATX 2. Identification number: Tank 510
3. Installation date: 1973 4. Volume: 2,520,000 gallons
5. Inside tank diameter: 95 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 3.5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average t~roughput: 2571948,405 gallons per year 12. Turnovers/yearly 102.4Monthly Weekly
13. Average liquid height (feet)": 48 14. Access hatch: 0 Yes o No Number 1
15. Type of Seals: 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well 0 Yes o No Number 1
IZl Mechanical shoe Gauge hatch/
□ Resi lient filled sample well @Yes o No Number_1_
□ Liquid filled Roof drains □ Yes o No Number --
□ Vapor mounted Rim vents 0 Yes o No Number _1_
□ Liquid mounted Vacuum break @Yes o No Number_1_
□ Flexible wiper Roof leg @Yes o No Number~
b. Secondary seal : Ladder well □ Yes o No Number --Type: Wi~er, rim-mounted Column well □ Yes o No Number --
Other: 1 unslotted guide-~ole well
17. Shell Characteristics: 18. Type of Construction:
Condition: Good □ Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction : Welded □ Internal Floating Roof
Roof Type: Pontoon 0 External Floating Roof
Deck Construction: Welded □ Other (please specify)
Deck Fitting Category: Ty~ical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket □ Venting □ Carbon Adsorption □ Thermal Oxidation □ Other:
20. Single Liquid Information
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. -Avg . Temperature:
Vapor Pressure: -Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Form
21.
Chemical Name: -
-Organic Liquid Storage Tank
(Continued)
Chemical Components Information
Chemical Name: -See TANKS Percent of Total Liquid Weight:_ Percent of Total Liquid Weight: printout in r--
Molecular Weight: Appendix D. c--Molecular Weight:
Avg. Liquid Temperature: 1--Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM10 Lbs/hr __ Tons/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/hr __ Tons/yr voe 299 Lbs/hr 2.27 Tons/yr
HAPs 8.23 Lbs/hr (speciate) 0.06 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAO) at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
1. . Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11. Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon , double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21. Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Form 20
Organic Liquid Storage Tank
Site/Source""": _..a.H=a=n=n"""a'"'"1--=U~T ____ _
Date: -----=-1-=0/:...:1-=5=/2=0-=-0=8 ___ _
Equipment
1. Tank manufacturer: Unknown 2. Identification number: Tank111
3. Installation date: 1949 4. Volume: 1680000 gallons
5. Inside tank diameter: 80 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 3.5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 127,049,215 gallons per year 12. Turnovers/yearly 75.6 Monthly __ Weekly _
13. Average liquid height (feet): 48 14. Access hatch: QI Yes □ No Number 1
15. Type of Seals: 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well @Yes □ No Number 1
Ill Mechanical shoe Gauge hatch/
□ Resilient filled sample well @Yes □ No Number 1
□ Liquid filled Roof drains □ Yes o No Number __
□ Vapor mounted Rim vents □ Yes □ No Number __
□ Liquid mounted Vacuum break @Yes □ No Number_1_
□ Flexible wiper Roof leg ILi Yes o No Number 24
b. Secondary seal: Ladder well 121 Yes o No Number_1_
Type: Wi~er, rim-mounted Column well ILi Yes □ No Number_1_
Other:
17. Shell Characteristics: 18. Type of Construction:
Condition: Good □ Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction: Welded IZI Internal Floating Roof
Roof Type: Cone -Column Su~~orted □ External Floating Roof
Deck Construction: Welded □ Other (please specify)
Deck Fitting Category: T)l~ical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket □ Venting □ Carbon Adsorption □ Thermal Oxidation □ Other:
20. Single Liquid Information
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. t--Avg. Temperature:
Vapor Pressure: t--Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form . -Organic Liquid Storage Tank
(Continued)
21. Chemical Components Information
Chemical Name: -See TANKS Percent of Total Liquid Weight:_ Percent of Total Liquid Weight: printout in -
Molecular Weight: Appendix D. -Molecular Weight:
Avg . Liquid Temperature: -Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM10 Lbs/hr __ Tons/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/lir __ Tons/yr voe 123 Lbs/hr 0.94 Tons/yr
HAPs 3.29 Lbs/hr (speciate) 0.02 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAO) at (801} 536-4000 if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We wil l be glad to help!
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Site/Source,;_: _..:..H=a=n=n=a._, U"""T-'-------
Form 20 Date: ___ ....:1..:0:....:11=5"-=/2=0=0=8 ___ _
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: Matrix Service 2. Identification number: TBD
3. Installation date: ~ro~osed 2008 4. Volume: 2,520,000 gallons
5. Inside tank diameter: 100 feet 6. Tank height: 43'-11" feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 199,136,700 gallons per year 12. Turnovers/yearly 79 Monthly Weekly
13. Average liquid height {feet): 43 14. Access hatch: i;zJ Yes □ No Number 1
15. Type of Seals: 16. Deck Fittings:
a. Primary seals: Gauge float well i;zi Yes □ No Number 1
IZI Mechanical shoe Gauge hatch/
□ Resilient filled sample well l:Z!Yes □ No Number_1_
□ Liquid filled Roof drains □ Yes □ No Number __
□ Vapor mounted Rim vents □ Yes □ No Number --
□ Liquid mounted Vacuum break @Yes □ No Number 1
□ Flexible wiper Roof leg @Yes □ No Number~
b. Secondary seal: Ladder well @Yes □ No Number _1_
Type: Wi~er, rim-mounted Column well i;zJ Yes □ No Number_1_
Other:
17. Shell Characteristics: 18. Type of Construction:
Condition: New □ Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction: Welded 0 Internal Floating Roof
Roof Type: Cone-Column Su~~orted □ External Floating Roof
Deck Construction: Welded □ Other (please specify)
Deck Fitting Category: T)l~ical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket □ Venting □ Carbon Adsorption □ Thermal Oxidation □ Other:
20. Single Liquid Information
Liquid Name: See TANKS >---Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. >---Avg. Temperature:
Vapor Pressure: >---Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form . ✓ -Organic Liquid Storage Tank
(Continued)
21 . Chemical Components Inform ati on
f--Chemical Name: See TANKS Percent of Total Liquid Weight:_ printout in ._ Percent of Total Liquid Weight:
Molecular Weight: Appendix D. ~ Molecular Weight:
Avg . Liquid Temperature: ~ Avg . Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for th is device:
PM10 Lbs/hr __ Tons/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/hr __ Tons/yr voe 181 Lbs/hr 1.38 Ton s/yr
HAPs 5.31 Lbs/hr (speciate) 0.04 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAO) at (801 ) 536-4000 if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the· date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Re id vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11. Indicate average annual throughput (gallons).
12. Specify how many times the tank will be em ptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type ; pontoon, double deck, or self-supporting roof
Deck construction; bolted or we lded, sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction .
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria poll utants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
, TANKS 4.0 Report
Identification
User Identification:
City:
State:
Company:
Type of Tank:
Description:
Tank Dimensions
Shell Length (ft):
Diameter (ft):
Volume (gallons):
Turnovers :
Net Throughput(gal/yr):
Is Tank Heated (y/n):
Is Tank Underground (y/n):
Paint Characteristics
Shell Color/Shade:
Shell Condition
Breather Vent Settings
Vacuum Settings (psig):
Pressure Settings (psig)
TANKS 4.0.9d
Emissions Report -Summary Format
Solvent Tank
Hanna
Utah
Tank lndentification and Physical Characteristics
Chevron Pipe Line Company
Horizontal Tank
Solvent
N
N
Aluminum/Specular
Good
5.00
6.00
300.00
1.00
300.00
-0.03
0.03
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Page 1 of 4
10/14/2008
TANKS 4.0 Report
Solvent Tank -Horizontal Tank
Hanna, Utah
Mixture/Component Month
Solvent All
Daily Liquid Surf.
Temperature (deg F)
Avg. Min. Max.
57.19 49.02 65.36
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Liquid
Bulk
Temp
(deg F)
53.30
Vapor
Vapor Pressure {psia) Mal.
Avg. Min. Max. Weight.
0.1000 0.1000 0.1000 80.0000
Liquid
Mass
Fract.
Vapor
Mass
Fract.
Page 2 of 4
Mol.
Weight
120.00
Basis fo
Calcula1
l 0/14/2008
-TANKS 4. 0 Report
Emissions Report for: Annual
Solvent Tank -Horizontal Tank
Hanna, Utah
jcomponents
!solvent
11
II II
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Losses(lbs) I
Working Lossjj Breathing Lossll Total Emissions!
0.0611 27311 2781
Page 3 of 4
10/14/2008
TANKS 4. 0 Report Page 4 of 4 ·
10/14/2008
CHEVRON PIPE LINE COMPANY
HANNA STATION
EMISSIONS SUMMARY -2008 POTENTIAL
10/14/2008
Annual Annual Hourly
CAS Equipment Maintenance Emissions Emissions Emissions ETV"
Pollutant Number Unit Tanks' Fuqitive2 Fuqitive3 lb/vr ton/vr lb/hr lb/hr Hourlv Emission > ETV?
voe lb 12,788.25 11 ,244.25 500.00 24,532.50 12.27
HAPs
2,2,4-Trimethylpentane (isooctane) 540-84-1 lb 8.01 7.98 0.36 16.35 0.01 0.0019 NA No, air modeling not required
Benzene 71-43-2 lb 26.36 19.00 0.85 46.21 0.02 0.0053 0.027 No, air modeling not required
Biphenyl 92-52-4 lb 1.65 2.70 0.12 4.47 0.00 0.0005 0.064 No, air modeling not required
Cresci (-m) 108-39-4 lb 2.54 4.16 0.19 6.89 0.00 0.0008 1.13 No, air modeling not required
Ethyl benzene 100-41-4 lb g_o1 13.27 0.59 22.87 0.01 0.0026 22.1 No, air modeling not required
Hexane (-n) 110-54-3 lb 250.40 132.01 5.87 388.27 0.19 0.0443 9 No, air modeling not required
lsopropyl benzene (cumene) 98-82-8 lb 2.30 3.60 0.16 6.06 0.00 0.0007 12.5 No, air modeling not required
Naphthalene 91-20-3 lb 3.92 6.41 0.29 10.61 0.01 0.0012 2.7 No, air modeling not required
Toluene 108-88-3 lb 33.41 40.48 1.80 75.68 0.04 0.0086 3.8 No, air modeling not required
Xvlenes (mixed isomers) 1330-20-7 lb 42.64 63.87 2.84 109.34 0.05 0.0125 22.1 No, air modelinq not required
TOTAL HAPs lb 380.24 293.47 13.05 0.34
TOTAL voes ton 6.39 5.62 0.25 12.27
1. RVP 3.5 and RVP 5.0 used for TANKS.
2. Equipment fugitives are totals that include pumps seals, valves, flanges, and drains.
3. Maintenance includes one tank cleaning.
4. Emission threshold value, minimum, vertically restricted/fugitive releases <20 m from property boundary.
Utah Division of Air Quality, downloaded 9/24/2008; http://www.airquality.utah.gov/Planning/Modeling/NSR_Permit_Modeling/Modeling%20Guidelines/2007 ACGIH-Tl Vs.xis
ETV = emission threshold value
HAP = hazardous air pollutant
NA = not available
CHEVRON PIPE LINE COMPANY
HANNA STATION
INPUTS for EMISSIONS ESTIMATE -2008 POTENTIAL
10/14/2008
Fugitive Count
Source Number
Of Units
Drains (open-ended lines) 4
Valves 106
Flanges 35
Pump Seals 18
Others 10
Tank Configuration
Height Tank Volume
Tank# Tank Tvoe Primarv Seals Secondarv Seals Roof Diameter lftl /ftl (bbl) (gal)
111 Internal Floater Mechanical Shoe Wiper, Rim-mounted Cone 80 48 40,000 1,680,000
510 External Floater Mechanical Shoe Wiper, Rim-mounted Pontoon 95 48 60,000 2,520,000
520 External Floater Mechanical Shoe Wiper, Rim-mounted Pontoon 95 48 60,000 2,520,000
New Internal Floater Mechanical Shoe Wiper, Rim-mounted Cone 100 43.92 60,000 2,520,000
Potential Tank Throughput
Potential Annual Throughput (bbls)
15,804,500
RVP1 Fraction' TP (bbl)
Rangely Crude 2.42 58% 9,166,610
Condensate 4.67 30% 4,741,350
Black Wax Condensate Mix 4.08 12% 1,896,540
Total 100% 15,804,500
-Crude u 11
RVP used in Year
Tank# Product TP (bbl) TP (gal) Turnover TANKS) Installed
111 Rangely Crude (33%) 3,024,981 127,049,21 5 75.6 3.5 1949
510 Rangely Crude (67%) 6,141 ,629 257,948,405 102.4 3.5 1973
520 Black Wax Condensate Mix 1,896,540 79,654,680 31.6 5.0 1972
New Condensate 4,741 ,350 199,136,700 79.0 5.0 TBD
Total 15,804,500 663,789,000
1Reid vapor pressure (RVP) was determined in laboratory tests.
2Fractional throughput based on design maximum daily throughput of 43,300 bbl/day, 13,000 bbl/day ~f condensate, 25,000
bbl/day of Rangely crude, and 5,300 bbl/day of black wax condensate mix.
TP = throughput
RVP = Reid vapor pressure
Conversions
bbls = 42 gals
CHEVRON PIPE LINE COMPANY
HANNA STATION
FUGITIVE EMISSIONS -2008 POTENTIAL
10/14/2008
Fui;iitive VOCs
Emisson Emisson
Number of Factors1 Factors Emissions2 Emissions
Description Units (kci/hr/source) (lb/hr/source) (lb/yr) (ton/yr)
Valves 106 2.50E-03 5.50E-03 5,107.08 2.55
Pump Seals 18 1.30E-02 2.86E-02 4,509.65 2.25
Others 10 7.50E-03 1.65E-02 1,445.40 0.72
Connectors 0 2.10E-04 4.62E-04 0.00 0.00
Flanges 35 1.10E-04 2.42E-04 74 .20 0.04
Open ended lines (drains) 4 1.40E-03 3.08E-03 107.92 0.05
Equipment Fugitives 11 ,244.25 5.62
Maintenance Fugitives:$ 500.00 0.25
TOTAL FUGITIVES, voes 11,744.25 5.87
1. Emission fractors from "Protocol for Equipment Leak Emission Estimates", EPA-453/R-95-017, November 1995.
Table 2-4 Oil and Gas Production, emission factors for light oil service.
2. Emissions= (# of units)(Emission Factor)(24 hr/day)(365 day/yr)
3. Maintenance includes one tank cleaning.
Conversion: 1 kg = 2.2 lb; 1 ton = 2000 lb
Fugitive HAPs
Equipment Maintenance
Weight Fugitive Fugitive Total
Pollutant Fraction1 (lb/yr) (lb/yr) (lb/yr)
voes 11,244.25 500.00 11 ,744.25
2,2,4-Trimethylpentane (isooctane) 0.00071 7.98 0.36 8.34
Benzene 0.00169 19.00 · 0.85 19.85
Biphenyl 0.00024 .2.70 0.12 2.82
Cresol (-m) 0.00037 4.16 0.19 4.35
Ethylbenzene 0.00118 13.27 0.59 13.86
Hexane (-n) 0.01174 132.01 5.87 137.88
lsopropyl benzene 0.00032 3.60 0.16 3.76
Naphthalene 0.00057 6.41 0.29 6.69
Toluene 0.0036 40.48 1.80 42.28
Xvlenes (mixed isomers) 0.00568 63.87 2.84 66.71
TOTAL FUGITIVE HAPs (lbs.) 293.47 13.05 306.52
1. Weight fraction from API Publication 4723, Nov 2002 (PERF data); Crude Oil.
CHEVRON PIPE LINE COMPANY
HANNA STATION
TANK EMISSIONS -2008 POTENTIAL
10/14/2008
Description CAS Unit Tank #TBD Tank 111 Tank 510 Tank 520 Total Comment
Annual Throughput aal 199,136,700 127,049,215 257,948,405 79,654,680 663,789,000 15,804,500 bbl throuqhput
2,2,4-Trimethylpentane (isooctane) 00540-84-1 lb 1.84 1.25 2.74 2.19 8.01
Benzene 00071-43-2 lb 5.50 3.32 8.60 8.95 26.36
Biphenyl 00092-52-4 lb 0.46 0.37 0.62 0.19 1.65
Cresci (-m) 00108-39-4 lb 0.71 0.57 0.96 0.30 2.54
Ethyl benzene 00100-41-4 lb 2.41 1.86 3.33 1.42 9.01
Hexane (-n) 00110-54-3 lb 48.41 26.36 78.88 96.75 250.40
lsopropyl benzene 00098-82-8 lb 0.63 0.50 0.86 0.31 2.30
Naphthalene 00091 -20-3 lb 1.10 0.88 1.48 0.46 3.92
Toluene 00108-88-3 lb 8.25 5.96 11.83 7.36 33.41
Xylenes (mixed isomers) 01330-20-7 lb 11.48 8.92 15.80 6.44 42.64
Total Tank VOCs lb/yr 2,755.29 1,873.79 4,547.70 3,611.47 12,788.25
lb/hr 181.17 123.21 299.03 237.47 840.87
ton/vr 1.38 0.94 2.27 1.81 6.39
Total Annual Tank HAPs (lb) lb/vr 80.80 49.98 125.09 124.37 380.24
lb/hr 5.31 3.29 8.23 8.18 25.00
ton/yr 0.04 0.02 0.06 0.06 0.19
1. Results from TANKS 4.09d, ran 10/14/2008.
2. Speciation of HAPs used in TANKS based on API Publication 4723, Nov 2002 (PERF data).
HAP= hazardous air pollutant
TRI = toxic release inventory
2007 ACGIH Threshold Limit Values (TLVS), Toxic Screening Levels (TSLs) and Emission Threshold Values (ETVs)
The purpose of this document is to serve as aid to NSR Engineers, Consultants, and the General Public in their interpretation of the applicability
of UACR307-410-5 when preparing or reviewing a Notice of Intent.
UACR307-410-5 requires any source submitting a NOi, which proposes to increase emission of HAP, to use Table 2 in the rule to determine
whether or not a dispersion modeling analysis of each pollutant is required as part of a complete NOi. If new emissions of the HAP
(expressed in lb/hr) exceeds the emission threshold value, dispersion modeling is required .
When selecting the proper Emission Threshold Factor, the folowing release scenario should be determined as follows.
"Vertically Restricted Emissions Release" means the release of an air contaminant through a stack or opening whose flow is directed
in a downward or horizontal direction due to the alignment of the opening or a physical obstruction placed beyond the opening,
or at a height which is less than 1.3 times the height of an adjacent building or structure, as measured from ground level.
"Vertically Unrestricted Emissions Release" means the release of an air contaminant through a stack or opening whose flow is directed upward
without any physical obstruction placed beyond the opening, and at a height which is at least 1.3 times the height of an adjacent building or structure,
as measured from ground level.
The lb/yr and TPY values calculated for chronic and carcinogenic HAP below are based on the assumption that the
source operates continuously (8760 hr/yr).
Acute values are express in lb/hr only, and emission limits or emission levels for acute HAP should not be expressed or calculated
in lb/hr or TPY. This is due to the nature of the chemical itself, whereby very short term exposure to high concentrations of the HAP
will result in immediate adverse health effects in the exposed individual.
Therefore, when evaluating acute HAP for the determination of modeling requirements, ALWAYS evaluate it based
on the maximum potential emission rate possible for that process. Do not back-calculate the lb/hr emission rate from
the sources proposed pounds or tons per year emission level listed in the NOi.
The range of emission threshold values are:
Acute
Chronic
Carcinogenic
Minimum ETF -0.038
Minimum ETF - 0.051
Minimum ETF -0.017
For each type of HAP, there is a minimum and maximum emissions threshold factor (ETF). They are:
Maximum ETF - 0.310
Maximum ETF - 0.368
Maximum ETF -0.123
Using these values , we are able to calculate the minimum emission rate for each type of HAP such that any source operating with a
proposed lb/hr emission level less than this value would not be required to perform a dispersion modeling analysis for this NOi process.
Similarly, using these values , we are able to calculate the maximum emission rate for each type of HAP such that any source operating
with a proposed lb/hr emission level greater than this values would inevitably be required to perform a dispersion modeling analysis
for this NOi process.
However, if the source's proposed emission rate is greater than the minimum emission rate , but less than the maximum emission
rate listed in the table below, the reviewing engineer will have to review the addition information required to be submitted under
R307-410-4 to determine if modeling is required (ie, pollutant release type and distance to property boundary).
A listing of TL Vs, TS Ls, and minimum and maximum ETVs are shown in the first half of the table below.
The full range of ETVs for all ETFs are listed in the second half of this document.
Utah Division of Air Quality, downloaded 9/24/2008;
http://www.airquality.utah.gov/Planning/Modeling/NS R _Permit_ Modeling/Modeling%20Guidelines/2007 ACG I H-TL Vs.xis
2007 ACGIH Threshold Limit Values (TLVS), Toxic Screening Levels (TSLs) and Emission Threshold Values (ETVs)
Show
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
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X
X
X
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X
ACUTE
Hazardous
Air Pollutants
CARCINOGENIC
Hazardous
Air Pollutants
Benzene (including benzene for gasol
CHRONIC
Hazardous
Air Pollutants
Biphenyl
Cresols/Cresylic acid
Cumene
Ethyl benzene
Hexane
Naphthalene
Toluene
Xylenes (isomers and mixture)
ACUTE
Hazardous
Air Pollutants
CARCINOGENIC
Hazardous
Air Pollutants
Benzene (including benzene for gasol
CHRONIC
Hazardous
Air Pollutants
-~
Biphenyl
Cresols/Cresylic acid
Cumene
Ethyl benzene
Hexane
Naphthalene
Toluene
Xylenes (isomers and mixture)
Health
Classification
Health
Classification
A1 Care.
Health
Classification
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Health
Classification
Health
Classification
A1 Care.
Health
Classification
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Utah Division of A ir Quality, downloaded 9/24/2008;
Toxic Emission Rate Below
Screening Which Modeling
Applicable TLV-Ceiling TLV-Ceiling Molecular Levels Would Never Be Triggered
Factor 1-Hour 1-Hour Weight (TSLs) Under UAC307-410-5
Safety (uglm3) (ppm) 1-Hour Average 'ETF=0.038 I
ug/m3 lb/hr lb/day TPY
Toxic Emission Rate Below
Screening Which Modeling
Applicable TLV-TWA TLV-TWA ~olecular Weigl Levels Would Never Be Triggered
Factor 8-Hour 8-Hour (TSLs) Under UAC307-410-5
Safety (ug/m3) (ppm) 24-Hour Average 'ETF=0.017 l"Continious operations
uglm3 lb/hr I , lb/yr TPY
30 1,597 0.5 78.11 53 0.027 I 238 0.12
Toxic Emission Rate Below
Screening Which Modeling
Applicable LV-TWA(ug/m TLV-TWA ~olecular Weigl Levels Would Never Be Triggered
Factor 8-Hour 8-Hour (TSLs) Under UAC307-410-5
Safety (ppm) 24-Hour Average 'ETF=0.051 ·continious operations
ug/m3 lb/hr lb/yr TPY
30 1,261 0 154.20 42 0.064 564 0.28
30 22,115 5.00 108.14 737 1.13 9,880 4.94
30 245,787 50.00 120.19 8,193 12.5 109,808 54.9
30 434,192 100.00 106.16 14,473 22.1 193,980 97.0
30 176,237 50.00 86.18 5,875 9.0 78,736 39.4
30 52,429 10.00 128.19 1,748 2.7 23,423 11.7
30 75,362 20.00 92.13 2,512 3.8 33,669 16.8
30 434,192 100.00 106.16 14,473 22.1 193,980 97.0
Acute Emission Threshold Values (in lb/hr)
Distance to Property Boundary and Emission Threshold Factors
Vertically Restricted/Fugitive Releases Vertically Unrestricted Releases
<20m 20-50 m 50-100 m >100 m <50 m 50-100 m >100 m
0.038 0.051 . 0.092 0.180 0.154 0.224 0.310
Carcinogenic Emission Threshold Values (in lb/hr)
Distance to Property Boundary and Emission Threshold Factors
Vertically Restricted/Fugitive Releases Vertically Unrestricted Releases
<20 m 20-50 m 50-100 m >100 m <50 m 50-100 m >100 m
0.017 0.022 0.041 0.090 0.066 0.081 0.123
0.0272 0.0351 0.0655 0.1438 0.1054 0.1294 0.1965
Chronic Emission Threshold Values (In lb/hr)
Distance lo Property Boundary and Emission Threshold Factors
Vertically Restricted/Fugitive Releases Vertically Unrestricted Releases
<20 m 20-50 m 50-100 m >100 m <50 m 50-100 m >100 m
0.051 0.066 0.123 0.269 0.198 0.224 0.368
0.06 0.08 0.16 0.34 0.25 0.28 0.46
1.13 1.46 2.72 5.95 4.38 4.95 8.14
12.54 16.22 30.23 66.12 48.67 55.06 90.45
22.14 28.66 53.41 116.80 85.97 97.26 159.78
8.99 11.63 21.68 47.41 34.89 39.48 64.86
2.67 3.46 6.45 14.10 10.38 11.74 19.29
3.84 4.97 9.27 20.27 14.92 16.88 27.73
22.14 28.66 53.41 116.80 85.97 97.26 159.78
http://www.airquality.utah.gov/Planning/Modeling/NS R _Permit_ Modeling/Modeling%20Guidelines/2007 AGGI H-TL Vs.xis
Emission Rate Above
Which Modeling
Would Always Be Triggered
Under UAC307-410-5
'ETF=0.310
lb/hr lb/day TPY
Emission Rate Above
Which Modeling
Would Always Be Triggered
Under UAC307-410-5
'ETF=0.123 *Continious operations
lb/hr lb/yr TPY
0.20 1721 0.86
Emission Rate Above
Which Modeling
Would Always Be Triggered
Under UAC307-410-5
'ETF=0.368 •cantlnious operations
lb/hr lb/yr TPY
0.46 4,066 2.0
8.14 71,290 35.6
90.4 792,340 396.2
159.8 1,399,697 700
64.9 568,132 284
19.3 169,016 84.5
27.7 242,943 121
159.8 1,399,697 700
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Identification
· User Identification:
City:
State:
Company:
Type of Tank:
Description:
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Self Supp. Roof? (y/n):
No. of Columns:
Eff. Col. Diam. (ft):
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Color/Shade:
Roof Condition:
Rim-Seal System
Primary Seal:
Secondary Seal
Deck Characteristics
Deck Fitting Category:
Deck Type:
Deck Fitting/Status
Tank lndentification and Physical Characteristics
Hanna Tank #TBD -2008 Potential
Hanna
Utah
Chevron Pipe Line Company
Internal Floating Roof Tank
Condensate
N
Light Rust
White/White
Good
White/White
Good
Mechanical Shoe
Rim-mounted
Typical
Welded
100.00
2,520,000.00
79 02
1.00
1.00
Access Hatch (24-in. Diam.)/Unbolted Cover, Ungasketed
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
Column Well (24-in. Diam.)/Built-Up Col.-Sliding Cover, Ungask.
Ladder Well (36-in. Diam.)/Sliding Cover, Ungasketed
Roof Leg or Hanger Well/Adjustable
Sample Pipe or Well (24-in. Diam.)/Slit Fabric Seal 10% Open
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation, Gask.
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Quantity
1
1
6
1
32
1
1
Page 1 of 13
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank #TBD -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
Liquid
Daily Liquid Surf. Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure (psia) Mal. Mass
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract.
Crude oil (RVP 5) All 53.92 47.99 59.86 51.98 2.5505 N/A N/A 50.0000
1,2,4• Trimethylbenzene 0.0160 N/A N/A 120.1900 0.0023
2,2.4-Trimethylpentane (isooctane) 0.4987 N/A N/A 114.2300 0.0007
Benzene 0.9843 N/A N/A 78.1100 0.0017
Biphenyl 0.0008 N/A N/A 154.2000 0.0002
Cresol (•m) 0.0010 N/A N/A 108.1000 0.0004
Ethylbenzene 0.0876 N/A N/A 106.1700 0.0012
Hexane (-n) 1.6300 N/A N/A 86.1700 0.0117
lsopropyl benzene 0.0382 N/A N/A 120.2000 0.0003
Naphthalene 0.0019 N/A N/A 128.2000 0.0006
Toluene 0.2725 N/A N/A 92.1300 0.0036
Unidentified Components 2.6610 N/A N/A 49.2054 0.9716
Xylenes (mixed isomers) 0.0728 N/A N/A 106.1700 0.0057
Page 2 of 13
Vapor
Mass Mal. Basis for Vapor Pressure
Fract. Weight Calculations .
207.00 Option 4: RVP=5
0.0001 120.19 Option 2: A=7.04383, 8_=1573.267, C=208.56
0.0006 114.23 Option 2: A=6.8118, 8=1257.84, C=220.74
0.0027 78.11 Option 2: A=6.905, 8=1211.033, C=220.79
0.0000 154.20 Option 1: VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2: A=7.508, 8=1856.36, C=199.07
0.0002 106.17 Option 2: A=6.975, 6=1424.255, C=213.21
0.0311 86.17 Option 2: A=6.876, 8=1171.17, C=224.41
0.0000 120.20 Option 2: A=6.93666, 8=1460.793, C=207.78
0.0000 128.20 Option 2: A=7.3729, 8=1968.36, C=222.61
0.0016 92.13 Option 2: A=6.954, 8=1344.8, C=219.48
0.9631 214.40
0.0007 106.17 Option 2: A=7.009, 8=1462.266, C=215.11
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank #TBD -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
II Losses(lbs)
!components Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
!crude oil (RVP 5) 67.5111 1,923.7311 764 0411
I 1,2,4-Trimethylbenzene 0.0011 4.4811 o.osll
Biphenyl 0.0011 0.4611 0.0011
Cresci (-m) I 0 0011 0.7111 0.0011
lsopropyl benzene II 0.0011 0.6211 0.0211
Ethylbenzene 0.0111 2.2711 0.1311
Hexane (-n) 2.1011 22 sail 23.7311
Naphthalene o.ooll 11011 0.0011
Toluene 0.1111 69311 1 2211
Xylenes (mixed isomers) o.osll 10 9311 o.s1 II
2,2,4-Trimethylpentane (isooctane) 0 0411 1.3711 04411
Benzene 01811 3.2511 2.0611
Unidentified Components 65.0311 1,869.0411 735.8911
Page 3 of 13
Deck Seam Loss ll Total Emissions!
0.0011 2,755.291
0.0011 4.531
0.0011 0.461
0.00 11 0.711
0.00 11 0631
0.00 11 2.41 I
0 0011 48.41 1
o.ooll 1.1 ol
0.0011 8.251
0 0011 11.481
0 0011 1.841
0.0011 s.sol
00011 2,669.961
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Identification
User Identification:
City:
State:
Company:
Type of Tank:
Description:
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Self Supp. Roof? (yin):
No. of Columns:
Eff. Col. Diam. (ft):
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Color/Shade:
Roof Condition:
Rim-Seal System
Primary Seal:
Secondary Seal
Deck Characteristics
Deck Fitting Category:
Deck Type:
Deck Fitting/Status
Tank lndentification and Physical Characteristics
Hanna Tank 111 -2008 Potential
Hanna
Utah
Chevron Pipe Line Company
Internal Floating Roof Tank
Crude Oil
N
Light Rust
White/White
Good
White/White
Good
Mechanical Shoe
Rim-mounted
Typical
Welded
80.00
1,680,000.00
75.62
1.00
1.00
Access Hatch (24-in. Diam.)/Unbolted Cover, Ungasketed
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
Column Well (24-in. Diam.)/Built-Up Col.-Sliding Cover, Ungask.
Ladder Well (36-in. Diam.)/Sliding Cover, Ungasketed
Roof Leg or Hanger Well/Adjustable
. Sample Pipe or Well (24-in. Diam.)/Slit Fabric Seal 10% Open
Vacuum Breaker (10-in . Diam.)/Weighted Mech. Actuation, Gask .
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Quantity
1
1
1
1
24
1
1
Page 4 of 13
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 111 -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
Liquid
Daily Liquid Surf. Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure (psia) Mol. Mass
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract.
Crude Oil (RVP 3.5) All 53.92 47.99 59.86 51.98 1.5477 NIA NIA 60.0000
1,2,4-Trimethylbenzene 0.0160 NIA NIA 120.1900 0.0023
2,2,4-Trimethylpentane (isooctane) 0.4987 NIA NIA 114.2300 0.0007
Benzene 0.9843 NIA NIA 78.1100 0.0017
8iphenyl 0.0008 NIA NIA 154.2000 0.0002
Cresol (-m) 0.0010 NIA NIA 108.1000 0.0004
Ethylbenzene 0.0876 NIA NIA 106.1700 0.0012
Hexane (-n) 1.6300 NIA NIA 86.1700 0.0117
lsopropyl benzene 0.0382 NIA NIA 120.2000 0.0003
Naphthalene 0.0019 NIA NIA 128.2000 0.0006
Toluene 0.2725 NIA NIA 92.1300 0.0036
Unidentified Components 1.5727 NIA NIA 59.4493 0.9716
Xylenes (mixed isomers) 0.0728 NIA NIA 106.1700 0.0057
Page 5 of 13
Vapor
Mass Mol. Basis for Vapor Pressure
Fract. Weight Calculations
120.00 Option 4: RVP=3.5
0.0000 120.19 Option 2: A=7.04383, 8=1573.267, C=208.56
0.0005 114.23 Option 2: A=6.8118, 8=1257.84, C=220.74
0.0021 78.11 Option 2: A=6.905, 8=1211.033, C=220.79
0.0000 154.20 Option 1: VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2: A=7.508, 8=1856.36, C=199.07
0.0001 106.17 Option 2: A=6.975, 8=1424.255, C=213.21
0.0247 86.17 Option 2: A=6.876, 8=1171.17, C=224.41
0.0000 120.20 Option 2: A=6.93666, 8=1460.793, C=207.78
0.0000 128.20 Option 2: A=7.3729, 8=1968.36, C=222.61
0.0013 92.13 Option 2: A=6.954, 8=1344.8, C=219.48
0.9707 120.93
0.0005 106.17 Option 2: A=7.009, 8=1462.266, C=215.11
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 111 -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
II Losses(lbs)
I c omponents Rim Seal Lossll Withdraw! Lossll Deck Fitting Los_sll
Crude Oil (RVP 3.5) 37.5911 1,537.9711 298.2311
1,2,4-Trimethylbenzene 0.0011 3.5811 0.0111
Biphenyl o.oojl 03711 0.0011
Cresol (-m) 0.0011 0 5711 0.0011
lsopropyl benzene 0.0011 0.4911 0.0011
Ethyl benzene 0.0111 1.8111 0.0411
Hexane (-n) 0.9311 18.0611 7.3711
Naphthalene o ooll 0.8811 0.0011
Toluene o.osll 55411 0.3811
Xylenes (mixed isomers) 0.0211 8.7411 01611
2,2,4-Trimethylpentane (isooctane) 0 0211 1.0911 0 1411
Benzene o.08II 2.6011 06411
Unidentified Components 36.4911 1,494.2511 289.48 11
Page 6 of 13
Deck Seam Lossll Total Emissions!
0.0011 1,873.791
0.0011 3.6oj
0.0011 0.371
0 0011 0.571
0.0011 o.soj
0.0011 1.861
0 0011 26.361
o.ooll 0.881
0.0011 5.961
0.0011 8.921
00011 1.251
00011 3.321
0 0011 1,820.211
10/1 4/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Tank lndentification and Physical Characteristics
Identification
User Identification:
City:
Hanna Tank 510 -2008 Potential
Hanna
State: Utah
Company:
Type of Tank:
Description:
Chevron Pipe Line Company
External Floating Roof Tank
Crude Oil
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Characteristics
Type:
Fitting Category
Light Rust
White/White
Good
Pontoon
Typical
Tank Construction and Rim-Seal System
Construction: Welded
Primary Seal: Mechanical Shoe
Secondary Seal Rim-mounted
Deck Fitting/Status
Access Hatch (24-in. Diam.)/Bolted Cover, Gasketed
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
95.00
2,520,000.00
102.36
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation, Gask.
Unslotted Guide-Pole Well/Ungasketed Sliding Cover
Gauge-Hatch/Sample Well (8-in. Diam.)/Weighted Mech. Actuation, Gask.
Roof Leg (3-in. Diameter)/Adjustable, Pontoon Area, Ungasketed
Roof Leg (3-in. Diameter)/Adjustable, Center Area, Ungasketed
Rim Vent (6-in. Diameter)/Weighted Mech. Actuation, Gask.
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Quantity
1
1
1
1
1
17
16
1
Page 7 of 13
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 510 -2008 Potential -External Floating Roof Tank
Hanna, Utah
Liquid
Daily Liquid Surf. Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure (psia) Mel. Mass
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract.
Crude Oil (RVP 3.5) All 53.92 47.99 59.86 51.98 1.5477 N/A N/A 60.0000
1,2,4-Trimethylbenzene 0.0160 N/A N/A 120.1900 0.0023
2,2,4-Trimethylpentane (isooctane) 0.4987 N/A N/A 114.2300 0.0007
Benzene 0.9843 N/A N/A 78.1100 0.0017
Biphenyl 0.0008 N/A N/A 154.2000 0.0002
Cresci (-m) 0.0010 N/A N/A 108.1000 0.0004
Ethylbenzene 0.0876 N/A N/A 106.1700 0.0012
Hexane (-n) 1.6300 N/A N/A 86.1700 0.0117
lsopropyl benzene 0.0382 NIA N/A 120.2000 0.0003
Naphthalene 0.0019 N/A N/A 128.2000 0.0006
Toluene 0.2725 N/A N/A 92.1300 0.0036
Unidentified Components 1.5727 N/A N/A 59.4493 0.9716
Xy1enes (mixe~ isomers) 0.0728 N/A N/A 106.1700 0.0057
Page 8 of 13
Vapor
Mass Mol. Basis for Vapor Pressure
Fract. Weight Calculations
120.00 Option 4: RVP=3.5
0.0000 120.19 Option 2: A=7.04383, 6=1573.267, C=208.56
0.0005 114.23 .option 2: A=6.8118, 6=1257.84, C=220.74
0.0021 78.11 Option 2: A=6.905, 6=1211 .033, C=220.79
0.0000 154.20 Option 1: VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2: A=7.508, 6=1856.36, C=199.07
0.0001 106.17 Option 2: A=6.975, 6=1424.255, C=213.21
0.0247 86.17 Option 2: A=6.876, 6=1171 .17, C=224.41
0.0000 120.20 Option 2: A=6.93666, 6=1460.793, C=207.78
0.0000 128.20 Option 2: A=7.3729, 6=1968.36, C=222.61
0.0013 92.13 Option 2: A=6.954, 8=1344.8, C=219.48
0.9707 120.93
0.0005 106.17 Option 2: A=7.009, 6=1462.266, C=215.11
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 510 -2008 Potential -External Floating Roof Tank
Hanna, Utah
II Losses(lbs)
!components Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
Crude Oil (RVP 3.5) 306.7711 2,597.0611 1,650 .0111
1,2,4-Trimethylbenzene 0.0111 60511 o.osll
Biphenyl 0.0011 0.62II 0.0011
Cresol (-m) 0.0011 0 9611 0.0011
lsopropyl benzene 0.0011 0.8311 0.0311
Ethylbenzene 0.0411 3.0611 0.2211
Hexane (-n) 7.5911 30.4911 408011
Naphthalene 0.0011 1.4811 0.0011
Toluene 0.3911 9.3511 2.0911
Xylenes (mixed isomers) 0.16II 14.7511 08811
2,2,4-Trimethylpentane (isooctane) 0.1411 1 8411 0 7611
Benzene 0.6611 43911 3 5511
Unidentified Components 297 .7711 2,523.2211 1,601 .6111
Page 9 of 13 '
Deck Seam Lossll Total Emissions!
0.0011 4,553.841
0.0011 6.151
o ooll 0.621
0.0011 0.961
0.0011 0.861
0.0011 3.331
0.0011 78.881
0.0011 1.481
0 0011 11.831
0.0011 15 sol
0.0011 2 741
o.ooll 8.601
0.0011 4,422.601
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Tank lndentification and Physical Characteristics
Identification
User Identification:
City:
Hanna Tank 520 -2008 Potential
Hanna
State: Utah
Company:
Type of Tank:
Description:
Chevron Pipe Line Company
External Floating Roof Tank
Black Wax Condensate Mix
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Characteristics
Type:
Fitting Category
Light Rust
White/White
Good
Pontoon
Typical
Tank Construction and Rim-Seal System
Construction: Welded
Primary Seal: Mechanical Shoe
Secondary Seal Rim-mounted
Deck Fitting/Status
Access Hatch (24-in. Diam.)/Bolted Cover, Gasketed
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
95.00
2,520,000.00
31 .61
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation, Gask.
Unslotted Guide-Pole Well/Ungasketed Sliding Cover
Gauge-Hatch/Sample Well (8-in . Diam.)/Weighted Mech. Actuation, Gask.
Roof Leg (3-in. Diameter)/Adjustable, Pontoon Area, Ungasketed
Roof Leg (3-in. Diameter)/Adjustable, Center Area, Ungasketed
Rim Vent (6-in. Diameter)/Weighted Mech. Actuation, Gask.
Meterological Data used in !:;missions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Quantity
1
1
1
1
1
17
16
1
Page 10 of 13
10/14/2008
TANKS 4. 0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 520 -2008 Potential -External Floating Roof Tank
Hanna, Utah
Liquid
Daily Liquid Surf. Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure (psia) Mel. Mass
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract.
Crude oil (RVP 5) All 53.92 47.99 59.86 51.98 2.5505 N/A N/A 50.0000
1,2,4-Trimethylbenzene 0.0160 N/A N/A 120.1900 0.0023
2,2,4-Trimethylpentane (isooctane) 0.4987 N/A N/A 114.2300 0.0007
Benzene 0.9843 N/A N/A 78.1100 0.0017
Biphenyl 0.0008 N/A N/A 154.2000 0.0002
Cresci (-m) 0.0010 N/A N/A 108.1000 0.0004
Ethylbenzene 0.0876 N/A N/A 106.1700 0.0012
Hexane (•n) 1.6300 N/A N/A 86.1700 0.0117
lsopropyl benzene 0.0382 N/A N/A 120.2000 0.0003
Naphthalene 0.0019 N/A N/A 128.2000 0.0006
Toluene 0.2725 N/A N/A 92.1300 0.0036
Unidentified Components 2.6610 N/A N/A 49.2054 0.9716
Xylenes (mixed isomers) 0.0728 N/A N/A 106.1700 0.0057
Page 11 of 13
Vapor
Mass Mel. Basis for Vapor Pressure
Fract. Weight Calculations
207 .00 Option 4: RVP=5
0.0001 120.19 Option 2: A=7.04383, 6=1573.267, C=208.56
0.0006 114.23 Option 2: A=6.8118, 6=1257.84, C=220.74
0.0027 78.11 Option 2: A=6.905, 6=1211.033, C=220.79
0.0000 154.20 Option 1: VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2: A=7.508, 6=1856.36, C=199.07
0.0002 106.17 Option 2: A=6.975, 6=1424.255, C=213.21
0.031 1 86.17 Option 2: A=6.876, 6=1171.17, C=224.41
0.0000 120.20 Option 2: A=6.93666, 6=1460.793, C=207.78
0.0000 128.20 Option 2: A=7.3729, 6=1968.36, C=222.61
0.0016 92.13 Option 2: A=6.954, 6=1344.8, C=219.48
0.9631 214.40
0.0007 106.17 Option 2: A=7.009, 6=1462.266, C=215.11
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 520 -2008 Potential -External Floating Roof Tank
Hanna, Utah
II Losses(lbs)
!components Rim Seal Lossll Withdrawl Lossll Deck Fitting Loss ll
Crude oil (RVP 5) 440.7811 801.9711 2,370.7611
1,2,4-Trimethylbenzene 0 0311 1 8711 0.1411
Biphenyl 0.0011 0.1911 0.0011
Cresol (-m) 0.0011 0 3011 0.0011
lsopropyl benzene 0 0111 0.2611 o 0511
Ethylbenzene 0.0711 0.9511 0.4011
Hexane (-n) 13.6911 9.4211 73.6411
Naphthalene 0.0011 0.4611 00011
Toluene 0.7011 2.8911 37711
Xylenes (mixed isomers) 0.3011 4.5611 1 5911
I 2,2,4-Trimethylpentane (isooctane) 0.2511 0.5711 1.3611
I Benzene II 1. 1911 1 3611 6.4011
I Unidentified Components II 424.5411 779.1711 2,283.4011
Page 12 of 13
Deck Seam Lossll Total Emissions!
o ooll 3,613.51 I
o ooll 2.041
0.0011 0.191
0.0011 0.301
0 0011 0.311
o.ooll 1.421
00011 96.751
00011 0.461
0.0011 7.361
0 0011 6.441
0 0011 2.191
0.0011 8.951
0.0011 3,487.111
10/14/2008
TANKS 4.0 Report Page 13 of 13
TANKS 4.0.9d
Emissions Report -Summary Format
Total Emissions Summaries -All Tanks in Report
Emissions Report for: Annual
Tank Identification Losses (lbs)
Hanna Tank #TBD -2008 Potential Chevron Pipe Line Company Internal Floating Roof Tank Hanna, Utah 2,755.29
Hanna Tank 111 -2008 Potential Chevron Pipe Line Company Internal Floating Roof Tank Hanna, Utah 1,873.79
Hanna Tank 510 -2008 Potential Chevron Pipe Line Company External Floating Roof Tank Hanna, Utah 4,553.84
Hanna Tank 520 -2008 Potential Chevron Pipe Line Company External Floating Roof Tank Hanna, Utah 3,613.51
Total Emissions for all Tanks: 12,796.43
10/14/2008
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
FACILITY PERMIT THRU THRU EMIS EMIS
FACILITY NAME STATE DATE PROCESS NAME PUT PUT CONTROL DESCRIPTION LIMIT LIMIT 1
UNIT 1 UNIT
REFINERY MACT REQUIRES
PONCA CITY OK 7/1/2002 TANKS VARIES CERTAIN CONTROL DEVICES
REFINERY WHICH ARE INSTALLED ON THE
STORAGE TANKS.
REFINERY MACT REQUIRES
PONCA CITY OK 7/1/2002 TANKS VARIES CERTAIN CONTROL DEVICES
REFINERY WHICH ARE INSTALLED ON THE
STORAGE TANKS.
ATOFINA PORT TK-800 EFR ARTHUR TX 5/18/2001 TANK NONE INDICATED 4.05 LB/H
COMPLEX
ATOFINA PORT TK-801 EFR ARTHUR TX 5/18/2001 NONE INDICATED 4.16 LB/H
COMPLEX TANK
ATOFINA PORT TK-802 EFR ARTHUR TX 5/18/2001 NONE INDICATED 4.16 LB/H
COMPLEX TANK
ATOFINA PORT TK-805 EFR ARTHUR TX 5/18/2001 NONE INDICATED 2.78 LB/H
COMPLEX TANK
ATOFTNA PORT TK-8077 IFR ARTHUR TX 5/18/2001 NONE INDICATED 1.26 LB/H
COMPLEX TANK
BAYTOWN TX 4/5/2001 TANK ZTK-08 FLOATING ROOF OR 22 LB/H OLEFINS PLANT EQUIVALENT
BACT Analysis
POLLUTANT COMPLIANCE NOTES II
' -·
--
15
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
FACILITY PERMIT THRU THRU EMIS EMIS
FACILITY NAME STATE DATE PROCESS NAME PUT PUT CONTROL DESCRIPTION LIMIT LIMIT J
UNIT I UNIT
BAYTOWN TX 4/5/200 1 (2) TANKS ZTK-FLOATING ROOF OR 0.4 LB/H OLEFINS PLANT 09A&B EQUIVALENT
BAYTOWN FLOATING ROOF OR TX 4/5/2001 TANK ZTK-10 0.51 LB/H OLEFINS PLANT EQUIVALENT
BAYTOWN TX 4/5/2001 TANKZTK-I1 FLOATING ROOF OR 0.28 LB/H OLEFINS PLANT EQUIVALENT
SAINT-GO BAIN FUEL FUGITIVES
VETROTEX TX 11/13/2000 & DIESEL NONE INDICATED 3.06 LB/H
AMERICA STORAGE TANK
VALERO
REFINING INTERNAL FLOATING ROOF, COMPANY-TX 6/11/2002 TANKS 60000 GAUH 4013 LB/H
CORPUS CHRISTI MONTHLY EMISSIONS RECORD
REFINERY
VALERO
REFINING INTERNAL FLOATING ROOF, COMPANY-TX 6/11 /2002 TANKS 60000 GAUH 4013 LB/H
CORPUS CHRISTI MONTHLY EMISSIONS RECORD
REFINERY
MARATHON FIXED ROOF INTERNAL FLOATING ROOF;
PETROLEUM CO LA 12/27/2006 COMPLY WITH 40 CFR 63
LLC STORAGE TANKS SUBPART CC
MARATHON INTERNAL INTERNAL FLOATING ROOFS ;
PETROLEUM CO LA 12/27/2006 FLOATING ROOF COMPLY WITH 40 CFR 63
LLC STORAGE TANKS SUBPART CC
BACT Analvsis
POLLUTANT COMPLIANCE NOTES
-' ,I
FUGITIVE EM ISSIONS ARE AN
ESTIMATE ONLY.
"
,.
16
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
FACILITY PERMIT THRU THRU EMIS EMIS
FACILITY NAME STATE DATE PROCESS NAME PUT PUT CONTROL DESCRIPTION LIMIT LIMIT 1
UNIT 1 UNIT
MARATHON EXTERNAL EXTERNAL FLOATING ROOF;
PETROLEUM CO LA 12/27/2006 FLOATING ROOF COMPLY W 1TH 40 CFR 63
LLC STORAGE TANKS SUBPART CC
. BACT Analvsis
POLLUTANT COMPLIANCE NOTES
-
-,r
17
RBLCID
IL-0073
MT-0013
OK-0059
OK-0089
OK-0092
TX-0235
TX-0237
TX-0269
TX-0269
TX-0315
TX-0315
TX-0315
CHEVRON PIPE LINE CO.
HANNA STATION
Table B-1
Summary of VOC BACT Determinations (per EPA's RBLC) for Fugitives
THRU
FACILITY NAME FACILITY PERMIT PROCESS NAME THRU PUT CONTROL DESCRIPTION STATE DATE PUT UNIT
EXXONMOBIL OIL IL 8/19/2003 FUGITIVES NONE INDICATED CORPORATION
MONTANA REFINING MT 1/23/1998 LIQUID GASOLINE NONE INDICATED COMPANY FUGITIVE
FUGITIVE REFINERY MACT REQUIRES
INSPECTION AND MAINTENANCE OF PONCA CITY REFINERY OK 7/1/2002 COMPONENTS/EQUIPM ENT PUMP SEALS, VALVES, FLANGES, AND LEAKS PIPES.
TPI PETROLEUM INC., CRUDE UNIT FUGITIVE LEAK DETECTION AND REPAIR (OVA VALERO ARDMORE OK 6/9/2003
REFlNERY EMISSIONS &METHOD 21)
VALERO ARDMORE OK 1/13/2003 CRUDE UNIT FUGITIVE LEAK DETECTION AND REPAIR
REFINERY EMISSIONS PROGRAM
EMISSIONS ARE ESTIMATES, NOT
VALERO REFfN ING MAXIMUM ALLOWABLE RATES.
COMPANY-CORPUS TX 6/1 1/2002 FUGITIVES SPECIAL CONDITIONS APPLY FOR
MAINTENANCE AND COMPLIANCE OF CHRISTI REFINERY EQUIPMENT RELATED TO FUGITIVE
EMISSIONS OF voe, SEE PERM IT.
PORT ARTHUR TX 9/8/1998 FUGITIVES 28 LAER MONITORING AND
REFINERY MAINTENANCE PROGRAM
SWEENY TANK FARM TX 5/8/1996 PUMP PIT AREA FUGITIVES CONTROLLED WITH THE 28VHP LEAK
DETECTION AND REPA IR PROGRAM.
PROCESS FUG ITIVE EM ISSIONS ARE
SWEENY TANK FARM TX 5/8/1996 TANK AREA FUGITIVES CONTROLLED WITH THE 28VHP LEAK
DETECTION AND REPAIR PROGRAM.
EXXON MOBIL BRUP OFF-SITE FUGITIVES
BAYTOWN REFTNERY TX 7/12/1999 (COOLING TOWER, PUMP, NONE INDICATED
VAL)
EXXON MOBIL FLEXICOKING FUGITIVES LOAR PROGRAM (SEE SPECIAL
BAYTOWN REFINERY TX 7/12/1999 (FXK, FRACTIONATOR, LT CONDITION #13 IN PERMIT) ENDS)
EXXON MOBIL TX 7/12/1999 PIPE STILL 7 FUGITIVES LOAR PROGRAM (SEE SPECIAL
BAYTOWN REFINERY CONDITION #13 IN PERMIT)
BACT Analvsis
EMIS EMIS EMISLIMITl
LIMIT LIMIT AVG TIME
1 1 CONDITION UNIT
3.76 TPY
IO MG/L ....
REFINERY .,,,
MACT
10000 PPM leak detection, see
notes
see note
1655 LB/H
2.44 LB/H
1.83 LB/H
0.91 LB/H I -
3.2 LB/H
20.4 LB/H
0.91 LB/H
18
'•
RBLCID
TX-0315
TX-0315
TX-03 15
TX-0320
TX-0320
TX-0320
TX-0320
TX-0320
TX-0322
TX-0322
TX-0335
TX-0340
TX-0340
CHEVRON PIPE LINE CO.
HANNA STATION
Table B-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Fugitives
THRU FACILITY PERMIT THRU FACILITY NAME STATE DATE PROCESS NAME PUT PUT CONTROL DESCRIPTION
UNIT
EXXON MOBIL TX 7/12/1999 RESIDFTNfNG & PIPE STILL LOAR PROGRAM (SEE SPECIAL
BAYTOWN REFINERY 8 FUG ITIVES CONDITION #13)
EXXON MOBIL TX 7/12/1999 SCU 2 FUGITIVES LOAR PROGRAM (SEE SPECIAL
BAYTOWN REFINERY CONDITION #13 OF PERMIT)
EXXON MOBIL TX 7/12/1999 SOUR WATER STRIPPING LOAR PROGRAM (SEE SPECIAL
BAYTOWN REFINERY FUGITIVES CONDITION #13 OF PERMIT)
ALON USA BIG SPRING TX 9/2/1999 CRUDE COMPLEX 28VHP LOAR REFINERY FUGITIVES, 02CRUDEFUG
ALON USA BIG SPRING TX 9/2/1999 FUEL GAS TREATER 28VHP LOAR REFINERY FUGITIVES, I0FGTFUG
ALON USA BIG SPRING TX 9/2/1999 LDH FUGITIVES, 28VHP LOAR REFINERY 09LDHFUG
ALON USA BIG SPRING TX 9/2/1999 PDA FUGITIVES, 28VHP LOAR REFINERY 09PDAFUG
ALON USA BIG SPRING REFORMATE SPLITTER/CS
REFINERY TX 9/2/1999 COLUMN FUGITIVES, 28VHP LOAR
26MTEFUG
CITGO CORPUS CHRISTI PROCESS FUGITIVES, 517-REFINERY-WEST TX 10/15/1999 NONE INDICATED
PLANT SI4
CITGO CORPUS CHRISTI SRU PROCESS FUGITIVES, REFINERY-WEST TX I 0/15/1999 553-FUG -NONE INDICATED
PLANT
TRIGEANT CORPUS TX sn12000 FUGITIVES, FUGITIVES NONE INDICATED CHR ISTI
EXXON MOBIL TX 4/13/2001 PROCESS FUGITIVES, LSM, 28VHP LOAR PROGRAM BAYTOWN REFINERY LSMFUG
EXXON MOBIL TX 4/13/2001 STORAGE TANK 0806, INTERNAL FLOATING ROOF BAYTOWN REFINERY TK0806
BACT Analvsis
EMIS EMIS EMIS LIMIT I l LIMIT LIMIT I AVG TIME
I UNIT CONDITION
3.42 LB/H
4.2 LB/H
0.5 LB/H
8.03 LB/H
0.98 LB/H
0.5 1 LB/H
3 LB/H
055 LB/H
"""I
_,J
18.59 LB/H
1.05 LB/H
2.19 LB/H
12 LB/H
0.16 LB/H
19
RBLCID
.
TX-0348
TX-0348
TX-0348
TX-0348
TX-0348
TX-0376
TX-0376
TX-0376
TX-0376
TX-0379
TX-0379
TX-0416
LA-0211
CHEVRON PIPE LINE CO.
HANNA STATION
Table B-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Fugitives
THRU
FACILITY NAME FACILITY PERMIT PROCESS NAME THRU PUT CONTROL DESCRIPTION STATE DATE PUT UNIT
DIAMOND SHAMROCK TX 10/19/200 I FUGITIVES-NONE INDICATED MCKEE PLANT ISOMERIZATION, F-9 I
DIAMOND SHAMROCK TX 10/19/200 1 FUGITIVES -NO. 3 NONE INDICATED MCKEE PLANT REFORMER
DIAMOND SHAMROCK TX I 0/19/2001 FUGITIVES -NO. 3 SRU , F-NONE INDICATED MCKEE PLANT 90
DIAMOND SHAMROCK TX 10/19/2001 FUGITIVES -NO. 4 NONE INDICATED MCKEE PLANT HYDROTREATER, F-88
DIAMOND SHAMROCK TX 10/19/2001 FUGITIVES-SPLITTER, F-89 NONE INDICATED MCKEE PLANT
DOW TEXAS TX 11/26/2002 PIPING FUGITIVES, NONE INDICATED OPERATIONS FREEPORT PROJECT A, A50FUO I
DOW TEXAS TX 11/26/2002 PIPING FUGITIVES, NONE INDICATED OPERATIONS FREEPORT PROJECT B, B73FUOI
DOW TEXAS TURBINE LUBRICATION
OPERATIONS FREEPORT TX 11/26/2002 FUGITIVES, PROJECT A, NONE IN DICATED
A50VI
DOW TEXAS TURBINE LUBRICATION
OPERATIONS FREEPORT TX 11/26/2002 FUGITIVES, PROJECT B, NONE INDICATED
B73V4
EXXONMOBIL FOLLOW PROCEDURES FOR LEAK
TX 6/10/2002 FCCU FUGITIVES PREVENTION, DETECTION, AND BEAUMONT REFINERY REPA IR.
FOLLOW PROCEDURES FOR LEAK EXXONMOBIL TX 6/10/2002 FCCU FUGITIVES PREVENTION, DETECTION, AND BEAUMONT REFINERY (PRESCRUBBER), 06FG-001 REPA IR.
SHELL OIL DEER PARK TX 11/24/1999 FUG ITIVE, PIPING LEAK DETECTION AND REPAIR
PROGRAM
MARATHON LA 12/27/2006 FUGITIVE EM ISSIONS LA REFINERY MACT PETROLEUM CO LLC
BACT Analvsis
EMIS EMIS EMISLIMITl
LIMIT LIMIT AVG TIME .
1 1 CONDITION UNIT
1.46 LB/H
1.04 LB/H .....
,
0.21 LB/H
1.2 LB/H
0.23 LB/H
0.136 LB/H
0.136 LB/H
0.006 LB/H
0.006 LB/H
9.84 LB/H -
I _,
9.85 LB/H
0.09 LB/H
20
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•
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l T
SCALC:1••40'
,l!!!!!!:. ___ fOR APPROVAL ___ FOR CONSTRUCTION I ,OR REV1EW ---F'OR BID I ifNGlobal ___ mR REF£Rt•ct ___ ""' AS-eu1Lr ~ 11.JJOJ,....., -,... »t1 ___ FOR PERMIT REQUEST ~~-,
IICF'CRC:NCC IMM,1/INGS
1----------+-----+------+------l◊ 0 ~RC~=l~~ ~!_~i~ ma....
Plpoln
PLOT PLAN
HANNA PUMP STATION
HANNA.!. DUCHESNE COUNTY
I--------+----+-----+----,◊ ◊ SCH.[~
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CPR' G OCPT. ___ (HG. D[PT.
COST CODC UTF0 16-A-00001 A
7
2
3
4
6
J
I Process Flow Diagram I
Pipeline from
Rangely Oil Field
Potent
Throu.
=43,3
=15,80
11
ay
ls/yr
•
Tank ·
i.
. T-520 .
.. 60,000 '
bbl
CHEVRON PIPE LINE COMPANY
HANNA STATION
.~
Fugitive Emissions
-Valves, Fittings,
Pump Seals Tank
-Maintenance Emi ssions
I I
,i,
• • • : Tanks ', Tanks Tank <
•~ T-510 T-111 ~ #TBD
i. 60,000 . 40,000 60,000
• bbl bbl bbl
~
..
, Pipeline to the
Salt Lake Refineries
UTAH DIVISION OF AIR QUALITY
SOURCE PLAN REVIEW
Jim Robbins
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
RE:
Review Engineer:
Date:
Notice of Intent Submitted:
Plant Contact:
Phone Number:
Fax Number:
Source Location:
Project Number: NSR0102130001
Hanna Petrol um Pipeline Pumping Station
Duchesne County; CDS B; Attainment Area, NSPS (Part
60)
Tim Dejulis
Not locked
November 17, 2008
Jim Robbins
[phone]
801-975-2323
40700 West 7000 North, Hanna, UT
Duchesne County
4,472,294 m Northing, 520,536 m Easting, UTM Zone 12
UTM Datum: NAD83
DAQ requests that a company/corporation official read the attached draft/proposed Plan Review with
Recommended Approval Order Conditions. If this person does not understand or does not agree with the
conditions, the review engineer should be contacted within five days after receipt of the Plan Review. If
this person agrees with the Plan Review and Recommended Approval Order Conditions, this person
should sign below and return (FAX# [phone]) within 10 days after receipt of the conditions. If the
review engineer is not contacted within IO days, the review engineer shall assume that the
company/corporation official agrees with this Plan Review and will process the Plan Review towards
final approval. A public comment period wi ll be required before the Approval Order can be issued.
Applicant Contact ____________________________ _
(Signature & Date)
Engineering Review: Chevron USA Pi peline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
Not locked
Page I
ABSTRACT
Chevron Pipeline Company has requested permi ssion to operate the Hanna petroleum pumping station as
a stationary area source. The Hanna station receives crude oil, condensible hydrocarbons, and bl ack wax
throughput from the company owned pipeline on it way to Salt Lake City. The Hanna station serves as a
buffer to pipeline operations allowing production to ebb and flow while at the same time maintaining a
consistent throughput within the pipeline.
Plant equipment includes four storage tank s (one with 1,680,000 gallon capacity and three with 2,520,000
gallon capacity), electric pump motors, and various comfort heating equipment items rated less than
5,000,000 Btu/hr each.
The emissions, in tons per year, will be as follows:
VOC = 12.27, HAPs = 0.33
SOURCE SPECIFIC DESIGNATIONS
Nonattainment or Maintenance Areas Impacted:
%%:udaq_ao_impacts%%
Applicable Programs:
Attainment Area, Subpart (No subparts) applies to Petroleum Pumping Station
NSPS (Part 60), Subpart Kb: VolatLiq/PetroStorageVessel 7/23/84 applies to Petroleum Pumping
Station
Description of Proposal:
Changes: Chevron Pipeline Company intends to establish a petroleum pumping station as a new
stationary area source. Crude oil , condensible hydrocarbons, and black wax are transported by the
pipeline to customers in Salt Lake City. The pump ing stati on employs large storage tanks and electrical
pumps.
Permit History:
When issued, the ap proval order shall supersede or will be based on the fo llowing doc uments:
Is Deri ved From Original NOi dated November 17, 2008
Emissions Summary:
Estimated Criteri a Pollutant Potential Emissions
Volatile Organi c Compound s
Estimated Hazard ous Air Po llutant Potenti al Emiss ions
12.27 tons/yr
2,2,4-Trimethylpentane (CAS #54084 1) .01 tons/yr
Engineering Review: Chevron USA Pipeline Company: Han na Pumping Station -Hanna Petro lum Pipeline Pumping Station
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Page 2
Benzene (Including Benzene From Gasoline)
(CAS #71432)
Ethyl Benzene (CAS #100414)
Hexane (CAS #110543)
Naphthalene (CAS #91203)
Toluene (CAS # 108883)
Xylenes (Isomers And Mixture) (CAS #1330207)
Total hazardous air pollutants
Best Available Control Technology Analysis:
.02 tons/yr
.01 tons/yr
.19 tons/yr
.01 tons/yr
.04 tons/yr
.05 tons/yr
.33 tons/yr
l. BACT review regarding Pl ant-wide -BACT Analysis
Chevron Pipeline Company has evaluated control options for all new, or modified equipment
items in terms of practical feasibility, control efficiency, and weighed the amount of pollution
controlled agai nst the cost of implementing a given technology, or strategy.
The va rious comfort heating devices do not require a BACT analysis due to the exclusion given
to these devices rated less than 5,000,000 Btu/hr -each in UAC R307-401-10.
The New Source Review Engineering Section recommends the following as BACT:
Storage Tanks
Use of submerged fill technology
Use of fl oating roof technology
Regul arl y visuall y in spect storage tanks (above ground), connecting suppl y or discharge
pipes, flanges, or gaskets, for gaps, tears or other .defects ·
Regul arl y maintaining storage tanks, and all connected equipment.
[Last updated Febru ary 19. 2009)
Modeling Results:
This source does not require modeling because the source is located in a Non-attainment area or
erniss ions increases are below thresholds establi shed in R307-410. [Last updated February 19, 2009]
Engi neering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 3
I.l
I.2
L3
I.4
I.5
I.6
I.7
RECOMMENDED APPROVAL ORDER CONDITIONS
The intent is to issue an air quality Approval Order (AO) authorizing the project with the following
recommended conditions and that fai lure to comply with any of the conditions may constitute a violation
of the order. The AO will be issued to and will apply to the following:
Name of Permittee:
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
Permitted Location:
Chevron USA Pipel ine Company: Hanna Pumping
Station
40700 West 7000 North
Hanna, UT 84031
UTM coordinates:
SIC code:
520,536 m Easting, 4,472,294 m Northing
4612 (Crude Petroleum Pipelines)
Section I: GENERAL PROVISIONS
All definitions, terms, abbreviations, and references used in this AO conform to those used in the
UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to
those rules. [R307-10 l]
The limits set forth in thjs AO shall not be exceeded without prior approval. [R307-401]
Modifications to the equipment or processes approved by this AO that could affect the emissions
covered by thi s AO must be reviewed and approved. [R307-401]
All records referenced in this AO or in other applicabl e rules. which are required to be kept by the
owner/operator, shall be made avai lable to the Executive Secretary or Executive Secretary's
representative upon request, and the records shall include the two-year period prior to the date of
the request. Unl ess otherwise specifi ed in this AO or in other applicable state and federal rules,
records shall be kept for a minimum of two (2) years. [R307-150]
At all times, including periods of startup, shutdown, and malfunction, owners and operators shall,
to the extent practicable, maintain and operate an y equipment approved under thi s AO including
associated air pollution control equipment in a manner consistent with good air pollution control
practice for minimizin g emi ssions. Determination of whether acceptable operating and
maintenance procedures are being used wi ll be based on information available to the Executive
Secretary which may include, but is not limited to, monitoring results, opacity observations, review
of operating and maintenance procedures, and in spection of the source. All maintenance .
performed on equipment authori zed by this AO shall be recorded. [R307-401]
The owner/operator shall comply with R307-150 Series. In ven tories. Testing and Monitoring.
[R307-150]
The owner/operator shall compl y with UAC R307-107. General Requirements: Unavoidable
Breakdowns. [R307-107]
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 4
II.A
II.A.I
II.A.2
11.A.3
II.A.4
II.A.5
. II.A.6
II.A.7
II.B .l.a
ll.B.l.b
II.B. l.c
II.B.l.d
Section II: SPECIAL PROVISIONS
The approved installations shall consist of the following equipment:
Petroleum Pumping Station
Hanna Petroleum Pipeline Pumping Station
Equipment Leaks
Various Process Connection/Process Control Device Equipment Leaks
Comfort Heaters
Various comfort heating devices rated less than 5,000,000 Btu/hr -each (listed for
informational purposes only)
Tank 510
2,520,000 gallon External Floating Roof Storage Tank (1973)
Tank 520
2,520,000 gallon External Floating Roof Storage Tank (1972)
Tank 111
1,680,000 gallon Internal Floating Roof Storage Tank (1949)
Tank 530
·2,520,000 gallon Internal Floating Roof Storage Tank (2009)
Requirements and Limitations
Visible e missions from any stationary poi nt or fugitiv e e mi ssion source associated with the
source or with the control facilities shall not exceed 20% opacity. Opacity observations of
emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix
A, Method 9. [R307-40 l]
The following limits shall not be exceeded:
9,166,610 barrels of crude oil throughput per rolling 12-month period
1,896,540 barrels of black wax condensate mix throughput per rolling 12-month period
4,741,350 barrels of condensate throughput per rolling 12-month period
To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the twentieth day of each month using data from the previous 12 months.
Records of crude oil throughput shall be kept for all periods when the plant is in operation.
Crude oil throughput shall be determined by examination of company and/or customer billing
records. The records of crude oil throughput shall be kept on a monthly basis. [R307-401]
C hevron Pipeline Company shall noti fy th e Executi ve Secretary in writing when the installati on
of the items appearing in the equipment li st is complete and is operational. To insure proper
credit when notifying the Executive Secretary, send your c01Tespondence to the Executi ve
Secretary, attn: Compliance Section. If the construction and/or in stallation is not complete
within 18 months from the date of this AO, the Executive Secretary shall be notified in writing
on the status of the construction and/or installation. At that time, the Executive Secretary shall
require documentation of the continuous construction and/or in stallation of the operation and
may revoke the AO. lR307-40J-18]
The owner/operator shall use propane or natural gas as fuel in the various comfort heating
devic es. [R 307-4011
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrol um Pipeline Pumping Station
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Page 5
Section III: APPLICABLE FEDERAL REQUIREMENTS
In addition to the requirements of this AO, all applicable provisions of the following federal programs
have been found to apply to this installation. This AO in no way releases the owner or operator from any
liability for compliance with all other applicable federal, state, and local regulations including UAC
R307.
NSPS (Part 60), Kb: VolatLiq/PetroStorage Vessel 7 /23/84
Engineering Rev iew: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Stati on
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Page 6
REVIEWER COMMENTS
The AO will be based on the following documents:
Is Derived From Original NOI dated November 17, 2008
l. Comment on an item originating in TMD regarding Petroleum Pumping Station
Additional information: Submitted February 12, 2009. [Last updated February 19, 2009]
2. Comment on an item ori gin ating in TMD regarding Petroleum Pumping Station
Additional information: Submitted January 20, 2009. [Last updated February 19, 2009]
3. Comment on an item originating in TMD regarding Petroleum Pumping Station
Additional information: Submitted January 28, 2009. [Last updated February 19, 2009)
4. Comment on an item originating in TMD regarding Petroleum Pumping Station
Additional information : Submitted February 11, 2009. [Last updated February 19, 2009]
5. Comment on an item origi nat ing in TMD regarding Petroleum Pumping Station
Comments from Chevron USA Pipeli ne: Source raised concerns regarding language contained
in conditions II.B.l.a, 11.B.l.b, and 11.B.l.d on several occasions (January 20, 2009, January 28,
2009, February 11 , 2009, and February 12, 2009) which delayed the start of the public comment
period. The comments were about the applicability of R307-l 50, the relevance of opacity
observations, the listing of fuel combustion devices mentioned in R307-401-10, and the timing
of updating rolling 12-month throughput totals. These negotiations resulted in the following
changes to the pl an review submitted to the source:
l. Opacity raised to 20% as per R307-205.
2. The frequency of monitoring of pipeline throughput will change from daily to monthly.
3. R307-401-10 fuel buring equipment will include a "for informational purposes on ly"
reference.
4. Fuel burning equipment will include natural gas as well as propane.
[Last updated February 19, 2009]
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 7
ACRONYMS
The following lists commonl y used acronyms and their associated translations as they appl y to this
document:
40CFR
AO
ATT
BACT
CAA
CAAA
CDS
CEM
CEMS
CFR
co
COM
DAQ
DAQE
EPA
HAPorHAPs
ITA
MACT
NAA
NAAQS
NESHAP
NOI
NOx
NSPS
NSR
PMIO
PM2.s
PSD
R307
R307-401
S02
Title IV
Title V
UAC
UDAQ
voe
Title 40 of the Code of Federal Regulations
Approval Order
Attainment Area
Best Available Control Technology
Clean Air Act
Clean Air Act Amendments
Classification Data System (used by EPA to classify sources by size/type)
Continuous emissions monitor
Continuous emissions monitoring system
Code of Federal Regulations
Carbon monoxide
Continuous opacity monitor
Division of Air Quality (typically interchangeable with UDAQ)
This is a document tracking code for internal UDAQ use
Environmental Protection Agency
Hazardous air pollutant(s)
Intent to Approve
Maximum Achievable Control Technology
Nonattainment Area
National Ambient Air Quality Standards
National Emission Standards for Hazardous Air Poll utants
Notice of Intent
Oxides of nitrogen
New Source Performance Standard
New Source Review
Particulate matter less than 10 microns in size
Particulate matter less than 2.5 microns in size
Prevention of Si gn ificant Deterioration
Rules Series 307
Rules Series 307 -Section 401
Sulfur dioxide
Title IV of the Clean Air Act
Title V of the Clean Air Act
Utah Administrative Code
Utah Di vision of Air Quality (typicall y interchangeable with DAQ)
Volatile organi c compounds
Engineering Review: Chevron US A Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 8
UTAH DIVISION OF AIR QUALITY
SOURCE PLAN REVIEW
Jim Robbins
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
RE:
Review Engineer:
Date:
otice oflntent Submitted:
Plant Contact:
Phone Number:
Fax Number:
Source Location:
Project Number: NSR0102130001
Hanna Petrolum Pipeline Pumping Station
Duchesne County; CDS B; Attainment Area, NSPS (Part
60)
Tim Dejulis
Not locked
November 17, 2008
Jim Robbins
(80 I) 975-2325
801-975-2323
40700 West 7000 North, Hanna, UT
Duchesne County
RECEIVED
JAN 2 0 2009
Division of Air Quality
4,472,294 m Northing, 520,536 m Easting, UTM Zone 12
UTM Datum: t-/AD83 __ -~ Comment [AH1]: These coordinates
~, in NAD27 is outside the boundary of the
DAQ requests that a company/corporation official read the attached draft/proposed Plan Review with
Recommended Approval Order Conditions. If this person does not understand or does not agree with the
conditions, the review engineer should be contacted within five days after receipt of the Plan Review. If
this person agrees with the Plan Review and Recommended Approval Order Conditions, this person
should sign below and return (FAX # [phone]) within IO days after receipt of the conditions. If the
review engineer is not contacted within IO days, the review engineer shall assume that the
company/corporation official agrees with this Plan Review and will process the Plan Review towards
final approval. A public comment period will be required before the Approval Order can be issued.
Applicant Contact __________________________ _
(Signature & Date)
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Perrolum Pipeline Pumping Station
Not locked
Page 1
'' facility.
, ' Deleted: NAD27
ABSTRACT
Chevron Pipeline Company has requested permission to operate the Hanna petroleum pumping station as
a stationary area source. The Hanna station receives crude oil, condensible hydrocarbons, and black wax
throughput from the company owned pipeline on it way to Salt Lake City. The Hanna station serves as a
buffer to pipeline operations allowing production to ebb and flow while at the same time maintaining a
consistent throughput within the pipeline.
Plant equipment includes four storage tanks (one with 1,680,000 gallon capacity and three with 2,520,000
gallon capacity), electric pump motors, and various comfort heating equipment items rated less than
5,000,000 Btu/hr each.
The emissions, in tons per year, will be as follows: voe =~2.27,_~~~s_ ~~-34 _________________________________________________ -< _ -
SOURCE SPECIFIC DESIGNATIONS
,, ,,
' ' '
Comment [AH2]: Increased
significant digits.
Deleted: 12.00
Deleted: 0.33
Nonattainment or Maintenance Areas Impacted: f /o %: udaq_ ao _ impacts% o/c _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -Comment [AH3]: Facility is in
Applicable Programs:
Attainment Area, Subpart (No subparts) applies to Petroleum Pumping Station
NSPS (Part 60), Subpart Kb: VolatLiq/PetroStorageVessel 7/23/84 applies to Petroleum Pumping
Station
Description of Proposal:
Changes: Chevron Pipeline Company intends to establish a petroleum pumping station as a new
stationary area source. Crude oil, condensible hydrocarbons, and black wax are transported by the
pipeline to customers in Salt Lake City. The pumping station employs large storage tanks and electrical
pumps.
Permit History:
When issued, the approval order shall supersede or wi ll be based on the fo llowing documents:
Is Derived From Original NOi dated ovember 17, 2008
Emissions Summary:
,
Estimated Criteria Pollutant Potential Emissions
Volatile Organic Compounds ---------------------------
!Estimated Hazardous Air Pollutant Potential Emission ._ __________________________________ -
2,2,4-Trimethylpentane (CAS #540841 ) .01 tons/yr
Benzene (Including Benzene From Gasoline) .02 tons/yr
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrol um Pipeline Pumping Station
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Page 2
attainment area.
Comment [AH4 ]: Increase significant
digits.
Deleted: 12
Comment [AHS]: Please add:
Biphenyl = 0.002 ton/yr
Cresol (m) = 0.002 ton/yr
Cumene = 0.003 ton/yr
(CAS #71432)
Ethyl Benzene (CAS #100414)
Hexane (CAS #110543)
Naphthalene (CAS #91203)
Toluene (CAS #108883)
Xylenes (Isomers And Mixture) (CAS #1330207)
Total hazardous air pollutants
Best Available Control Technology Analysis:
I. BACT review regarding Plant-wide
.01 tons/yr
.19 tons/yr
.01 tons/yr
.04 tons/yr
.05 tons/yr
~)jlqn~0'! __________________________ --1~De_leted __ :_.33 ______ ~
BACT Analysis: Chevron Pipeline Company has evaluated control options for all new, or
modified equipment items in terms of practical feasibility, control efficiency, and weighed the
amount of pollution controlled against the cost of implementing a given technology, or
strategy.The various comfort heating devices do not require a BACT analysis due to the
exclusion given to these devices rated less than 5,000,000 Btu/hr-each in UAC R307-401-
IO.The New Source Review Engineering Section recommends the following as BACT:
Storage Tanks
Use of submerged fill technology
Use of floating roof technology
Regularly visually inspect storage tanks (above ground), connecting supply or discharge
pipes, flanges, or gaskets, for gaps, tears or other defects
Regularly maintaining storage tanks, and all connected equipment [Last updated
December 29, 2008]
Modeling Results:
This source does not require modeling because the source is located in a Non-attainment area or
emissions increases are below thresholds established in R307-4 l 0. [Last updated December 29, 2008]
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 3
I.I
1.2
1.3
1.4
1.5
RECOMMENDED APPROVAL ORDER CONDITIONS
The intent is to issue an air quality Approval Order (AO) authorizing the project with the following
recommended conditions and that failure to comply with any of the conditions may constitute a violation
of the order. The AO will be issued to and will apply to the following:
Name of Permittee:
Chevron USA Pipeline Company
2875 S Decker Lake Dr Ste 150
West Valley City, UT 84119
Permitted Location:
Chevron USA Pipeline Company: Hanna Pumping
Station
40700 West 7000 orth
Hanna, UT 84031
UTM coordinates:
SIC code:
520,536 m Easting, 4,472,294 m Northing
4612 (Crude Petroleum Pipelines)
Section I: GENERAL PROVISIO S
All definitions, terms, abbreviations, and references used in this AO conform to those used in the
UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to
those rules. [R307-l O 1]
The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
Modifications to the equipment or processes approved by this AO that could affect the emissions
covered by this AO must be reviewed and approved. [R307-401]
All records referenced in this AO or in other applicable rules, which are required to be kept by the
owner/operator, shall be made available to the Executive Secretary or Executive Secretary's
representative upon request, and the records shall include the two-year period prior to the date of
the request. Unless otherwise specified in this AO or in other applicable state and federal rules,
records shall be kept for a minimum of two (2) years. [R307-401]. [R307-150]
At all times, including periods of startup, shutdown, and malfunction, owners and operators shall,
to the extent practicable, maintain and operate any equipment approved under this Approval Order
including associated air pollution control equipment in a manner consistent with good air pollution
control practice for minimizing emissions. Determination of whether acceptable operating and
maintenance procedures are being used will be based on information available to the Executive
Secretary which may include, but is not limited to, monitoring results, opacity observations, review
of operating and maintenance procedures, and inspection of the source. All maintenance
performed on equipment authorized by this AO shall be recorded. [R3 07-401]
I~_ - - - - - ->: - - - - - - - - - - -~ - - - - - - - - - ---- - - - - ---- --- - -- - - - - - --- - - --- - - - - ---,---~-~~:i!~:~:,,,.1~:Can7::nn!i°m
', warrant an inventory on a routine basis. 1.7 The owner/operator shall comply with UAC R307-107. General Requirements: Unavoidable
Breakdowns. [R307-107]
Engineering Review: Chevron USA Pipeline Company: Hanna Pwnping Station -Hanna Petrolwn Pipeline Pwnping Station
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Page 4
, However, the facility will submit an
, inventory as needed upon written request
, by DAQ.
Deleted: The owner/operator shall
comply with R307-150 Series.
Inventories, Testing and Monitoring.
[R307-150]'l!
II.A
II.A.I
II.A.2
II.A.3
II.A.4
II.A.5
ILA.6
II.A.7
11.B
rt.B.1.a
II.B.1.b
II.B.l.c
rt.B.1.d
Section 11: SPECIAL PROVISIONS
The approved installations shall consist of the following equipment:
Petroleum Pumping Station
Hanna Petroleum Pipeline Pumping Station
Equipment Leaks
Various Process Connection/Process Control Device Equipment Leaks
Tank 111
1,680,000 gallon Internal Floating Roof Storage Tank (1949)
Tank 510
2,520,000 gallon External Floating Roof Storage Tank (1973)
Tank 520
2,520,000 gallon External Floating Roof Storage Tank (1972)
Tank530
2,520,000 gallon Internal Floating Roof Storage Tank (2009)
Comfort Heaters
Various comfort heating devices rated less than 5,000,000 Btu/hr -each
Requirements and Limitations
L ____________________________________________________________ _
I\
I ' The following limits shall not be exceeded: I '
I '
9,166,610 barrels of crude oil throughput per rolling 12-month period
1,896,540 barrels of black wax condensate mjx throughput per rolling 12-month period
4,741,350 barrels of condensate throughput per rolling 12-month period
'
,b rolling 12-month total throughput will be calculated on a monthly basis and records shall be
made available to the Executive Secretary or Executive Secretary's representative upon request,
Recorqs of crude oi 1 throughput shall be kept for two years for all periods when the plant is in '
operation. Crude oil throughput shall be determined by examination of company and/or
customer billing records. J:~~0_7:~01 l __________________________________ _
' Chevron Pipeline Company shall notify the Executive Secretary in writing when the installation\
of the items appearing in the equipment list is complete and is operational. To insure proper
credit when notifying the Executive Secretary, send your correspondence to the Executive
Secret~ry, attn: Compliance Section. If the construction and/or installation is not complete
within 18 months from the date of this AO, the Exec;utive Secretary shall be notified in writing
on the status of the construction and/or installation. At that time, the Executive Secretary shall
requin(documentation of the continuous construction and/or installation of the operation and
may reyoke the AO. [R307-401-18]
I
I
I
Comment [AH7]: This facility is not a
source for PM. The only time opacity
may be a concern would be short-term
during construction.
Deleted: Visible emissions from any
stationary point or fugitive emission
source associated with the source or with
the control facilities shall not exceed 100/o
opacity. Opacity observations of
emissions from stationary sources shall
be conducted at an acceptable frequency,
in accordance with 40 CFR 60, Appendix
I A, Method 9. [R307-401] I
Deleted:,i
Deleted: To detennine compliance with
a rolling 12-month total, the
owner/operator shall calculate a new 12-
month total by the twentieth day of each
month using data from the previous 12
months. ' Deleted: The records of crude oil
throughput shall be kept on a daily basis ..
The owner/operator shall use propane or natural gas as fuel in the various~ heatin_g ____ --{ Deleted: compfon devices. ~----------~
J R307401l _____________________________________________________ -,~De_leted_:_. _____ ~
Section Ill: APPLICABLE FEDERAL REQUIREMENTS
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrol um Pipeline Pumping Station
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Page 5
In addition to the requirements of this AO, all applicable provisions of the following federal programs
have been found to apply to this installation. This AO in no way releases the owner or operator from any
liability for compliance with all other applicable federal, state, and local regulations including UAC
R307.
NSPS (Part 60), Kb: VolatLiq/PetroStorage Vessel 7 /23/84
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrol um Pipeline Pumping Station
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Page 6
REVIEWER COMMENTS
The AO will be based on the following documents:
Is Derived From
%% %%NEXT%,%
:uda %%NEXT%%
q_p
ermi
t C
mt_
nsr
%%
Original NOI dated ovember 17, 2008
Engineering Review: Chevron USA Pipeline Company: Hanna Pumping Station -Hanna Petrolum Pipeline Pumping Station
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Page 7
ACRONYMS
The following lists commonly used acronyms and their associated translations as they apply to this
document:
40CFR
AO
ATI
BACT
CAA
CAAA
CDS
CEM
CEMS
CFR
co
COM
DAQ
DAQE
EPA
HAP orHAPs
ITA
MACT
NAA
NAAQS
NESHAP
NOi
NOx
NSPS
NSR
PM10
PM2.5
PSD
R307
R307-401
S02
Title IV
TitleV
UAC
UDAQ
voe
Title 40 of the Code of Federal Regulations
Approval Order
Attainment Area
Best Available Control Technology
Clean Air Act
Clean Air Act Amendments
Classification Data System (used by EPA to classify sources by size/type)
Continuous emissions monitor
Continuous emissions monitoring system
Code of Federal Regulations
Carbon monoxide
Continuous opacity monitor
Division of Air Quality (typicall y interchangeable with UDAQ)
This is a document tracking code for internal UDAQ use
Environmental Protection Agency
Hazardous air pollutant(s)
Intent to Approve
Maximum Achievable Control Technology
Nonattainment Area
National Ambient Air Quality Standards
National Emission Standards for Hazardous Air Pollutants
Notice oflntent
Oxides of nitrogen
New Source Performance Standard
New Source Review
Particulate matter less than IO microns in size
Particulate matter less than 2.5 microns in size
Prevention of Significant Deterioration
Rules Series 307
Rules Series 307 -Section 401
Sulfur dioxide
Title IV of the Clean Air Act
Title V of the Clean Air Act
Utah Administrative Code
Utah Division of Air Quality (typically interchangeable with DAQ)
Volatile organic compounds
Engineering Review: Chevron USA Pipeline Company: Hanna Pwnping Station -Hanna Petrolwn Pipeline Pwnping Station
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Page 8
Chevron
November 13, 2008
Utah Division of Air Quality
Attn: Mr. Tim DeJulis
150 North 1950 West
Salt Lake City, Utah 84114-4820
()
-n
ra3\7~:)
1000-·
Global Gas
Chevron Pipe Line Company
2875 S Decker Lake Dr Ste 150
Salt Lake City, UT 84119
Tel [phone]
Fax [phone]
UTAH DEPARTMENT OF
ENVIRONMENTAL QUALITY ---·-. · 7
NOV 173)()8 ;
~--... --. .J
DIVISION OF ~IR QUALITY
Chevron Pipe Line Company -Hanna Facility Notice of Intent
~~'~
No \ o '2-.l °?:> ~cx..x:> 1
Dear Mr. DeJulis:
Please find attached a copy of the signed Chevron Pipe Line Company, Notice of Intent Permit
for the Hanna Facility. This signed copy is a duplicate of the information that Autumn Hu of
URS provided to you on October 20, 2008. Also attached is a check for the amount of $1,900.00
for the NOi processing fee.
Based on this information, the potential to emit for the Hanna Facility is 12.27 tons of VOC per
year (tpy), while the Hazardous Air Pollutants (HAP's) is _:S I ton per year. Due to the critical
nature of the weather, we would appreciate all efforts to expedite this permit as soon as possible.
If additional clarification and/or information are required, please contact Jim Robbins at (80 I)
975-2325.
Sincerely,
;{)/J;:;
1m Robbins
Environmental Specialist
Attachments
Chevron
NOTICE OF INTENT
HANNA STATION
CHEVRON PIPE LINE COMPANY
November3,2008
Prepared by:
URS
UTAH DEPARTMENT OF
ENVIRONMENTAL QUALITY -----. -7
1 ! I NOV 1 7 2008 !
DIVISION OF ~IA QUALITY
7 56 East Winchester Street, Suite 400
Salt Lake City, UT 84107
URS Project: 24584986
'
NOTICE OF INTENT
HANNA STATION
CHEVRON PIPE LINE COMPANY
November3,2008
TABLE OF CONTENTS
Fonn I
Form Id
Appendix A
Appendix B
Appendix C
Appendix D
Appendix E
General lnfo nnation
Emi ssions Information
Site Plan
Flow Diagram
Site Description
Emission Estimate
BACT Analysis
-
Utah Division of Air Quality
New Source Review Section
Form 1
General Information
Application for: 0 Initial Approval Order
Date 11/3/2008
D Approval Order Modification
AN APPROVAL ORDER MUST BE ISSUED BEFORE ANY CONSTRUCTION OR INSTALLATION CAN BEGIN. This is not a
stand alone document. Please refer to the Permit Application Instructions for specific details required to complete the
application. Please print or type all information requested. All information requested must be completed and submitted before
an engineering review can be initiated. If you have any questions, contact the Division of Air Quality at [phone] and ask
to speak with a New Source Review Engineer. Written inquiries may be addressed to: Division of Air Quality, New Source
Review Section, P.O. Box 144820, Salt Lake City, Utah 84114-4820.
Applicable base fee for engineering review and filing fee must be submitted with the application.
General Owner and Facility Information
1. Company name and address: 2. Company contact for environmental matters:
Chevron Pipe line Company Jim Robbins
2875 South Decker Lake Drive, Suite 150 Environmental Specialist
West Valley City, UT 84119 Phone No.: [phone]
Phone No.: [phone] Fax No.: [phone]
Fax No.: [phone]
3. Facility name and address (if different from above): 4. Owners name and address:
Hanna Station N/A
40700 West 7000 North
Hanna, UT 84031
Phone no.: None Phone no.: ( )
Fax no.: None Fax no.: ( )
5. County where the facility is located in: 6. Latitude & longitude, and/or UTM coordinates of plant:
Duchesne 4,472,294 N, 520,536 E
UTM, NAD 83, Zone 12 (meters)
7. Directions to plant or Installation (street address and/or directions to site) (include U.S. Coast and Geodetic Survey
map if necessary):
40700 West 7000 North
Hanna, UT 84031
8. Identify any current Approval Order(s): N/A
AO# Date AO# Date
AO# Date AO# Date
AO# Date AO# Date
9. If request for modification, permit# to be modified: DAQE # N/A DATED: I I
1 O. Type of business at this facility: Crude pipeline pump station
11. Total company employees greater than 100? 12. Standard Industrial Classification Code
4612 Crude petroleum pipelines
D Yes 0 No
Page 1 of 4
Approval Order Application
Form 1 (Continued)
13. Application for:
□ New construction 0 Modification
0 Existing equipment operating without permit □ Permanent site for Portable Approval Order
□ Change of permit condition □ Change of location
14 . For new construction or modification, enter estimated start date: Jan 2008 Estimated completion date: Sep 2009
15. For change of permittee. location or condition, enter 16. For existing equipment in operation without prior permit,
date of occurrence: N/A enter initial operation date: 1949
17. Has facility been modified or the capacity increased since November 29, 1969: D Yes 0 No
Process Information
18. Site plan of facility (Attach as Aooendix A) See APPendix A.
19. Flow diagram of entire process to include flow rates and other applicable information (Attach as Appendix B):
See Appendix B.
20. Detailed written process and equipment description. (Attach as Appendix C):
Description must include:
Process/Equip specific form(s) identified in the instructions
Fuels and their use Equipment used in process Description of product(s)
Raw materials used Operation schedules Description of changes to process (if applicable)
Production rates (including daily/seasonal variances)
See Appendix C. Includes Form 20 -Organic LiQuid Storage Tank
21 . Does this application contain justifiable confidential data? Yes 0 No
I Emissions Information I
22. Complete and attach Form 1 d. Emissions Information See Appendix D.
Include Material Safety Data Sheets for all chemicals or compounds that may be emitted to the atmosphere.
23. Identify on the site plan (see #18 above) all emissions points, building dimensions, stack parameters, etc.
See Appendix A.
Air Pollution Control Equipment Information
24 . List all air pollution control equipment and include equipment specific forms identified in the instructions.
AU --A . r. No air pollution control eQuipment. ,~ -~-
25. List and describe all compliance monitoring devices and/or activities (such as CEM, pressure gages). i\ttach as
A-,: .. r No compliance monitoring devices. -~~ ~-
26. Submit modeling for the project if reauired. See attached instructions. Modeling not reQuired.
27. Attach as Appendix ~ your proposal of what air pollution control devices, if any, or operating practices represents Best
Available Control Technology. Discuss and evaluate all air pollution control technologies relevant to your situation or
process. See Appendix E.
28. I hereby certify that the information and data submitted in and with this application is completely true, accurate and
complete, based on reasonable inquiry made by me and to the best of my knowledge and belief.
/ --~attlfe:'v'/ -Title Midcontinent Operational Manager, Northwest
'--_/{ -,v ) 29 . .L.. -30. Telephone Number 30 . Date: 11/3/2008 '--Brad ~asefwbt¼J / [phone]
/ -
Page 2 of 4
Approval Order Application
Form 1 Instructions
1. Identify the name, address, phone number, and fax number of the legal entity that operates the equipment.
2. Identify the person who Is to be contacted regarding this application; also include the phone number and fax number
of this person.
3. Identify the address where the equipment will be located.
4. If you are not the owner of the equipment under this application, enter the name, address, phone number, and fax
number of the owner.
5. Identify in what county the facility is located. If this is portable equipment, state in what county the first location is.
6. Indicate the technical location of the.facility so that it can be located on a map for modeling and inventory purposes.
The location can be read from a 7 .5 map.
7. Indicate the geographical location or address of facility and directions to site if needed for remote locations. For
example, Go five miles south on highway 1, turn left at farmhouse, go 1.5 miles.
8. List any valid Approval Orders (AO) which are for equipment at this site.
9. Indicate previous AO number (if any) and date for AO modification.
10. State the type of business you conduct at this facility.
11 . Indicate if the total number of people employed by your company is over 100 people.
12. Using the provided list of business codes (page 8), enter the code which best describes your business activity at this
facility.
13. Check all applicable boxes
New Construction: new equipment which has not yet been constructed and requires a permit to construct.
Existing Equipment Operating Without Permit: equipment which has been in operation without a prior permit
issued by the state.
Change of permit condition: permitted equipment which will be operated contrary to permit conditions.
Modification: existing equipment which is physically altered by the removal, addition, or non-identical replacement
of parts.
Permanent site: equipment will be located continuously at one site for more than 180 days.
Change of location : permitted equipment which will be transferred from one property to another.
14. Enter the start date and the completion date of any new installation, construction, or modification.
15. For cases in this category, enter the future date when the change is anticipated.
16. For this category of equipment, enter the date when this equipment was first operated.
17. This is for equipment that was operated before November 29, 1969. Indicate whether the facility has been modified
or increased capacity since that date.
18. Attach as Appendix A to the application a site plan in sufficient detail to identify: general location of site, buildings,
roads, process equipment, emission points, and site characteristics that may effect plume dispersion.
19. Attach as Appendix B to the application a flow diagram which illustrates the entire process from introduction of raw
materials to the emission of exhaust to the atmosphere and includes at least the following: generating equipment,
process equipment, control equipment, monitoring devices, duct work, hoods, fans, stacks, flow rates/direction,
gauges, etc.
20. Attach as Appendix C to the application a narrative description of the process and equipment to be permitted.
Essentially include a narrative of the flow chart above. The description must include equipment or process specific
forms as appropriate. The attached general supplemental process form (Form 2) must be filled out by all sources.
Please mark which forms below apply to this project. Forms available upon request are as follows:
Form 11 Internal Combustion Engines
Form 12 Incinerators
Form 13 Spray Booths
Form 14 Concrete Batch Plants
Form 15 Rock Crushing and Screening
Form 16 Soil/groundwater Remediation
Form 17 Diesel Powered Standby Generator
Form 18 Portable Hot Mix Drum Asphalt Plants
Form 19 Fuel Burning Equipment (Boilers, Heaters, Steam Generators)
Form 20 Organic Liquid Storage Tank
Form 21 Solvent Metal Cleaning (degreasers)
Form 22 Combustion Turbines
21 . To claim confidentiality on information submitted with this application, check "yes". Be sure that all submitted
information which you wish kept confidential is clearly marked as such. Also state the reason(s) for claiming
confidentiality per 40CFR2.208. Examples of acceptable reasons are trade secrets and production data. Note that
information on emissions and permits cannot be confidential.
3 of 4
New Source Review Application
Form 1 Instructions (Continued)
22. Attach a completed Form 1d, Emissions Information. Provide all MSD Sheets for all chemicals used.
23. List emission points and parameters on the site plan (#14 above).
24. Attach as Appendix D to the application a list of all air pollution control equipment. Must include form(s) as
appropriate. Please mark which forms apply to this project. Forms available upon request are as follows:
Form 3 Afterburners
Form 4 Flares
Form 5 Adsorption Unit
Form 6 Cyclone
Form 7 Condenser
Form 8 Electrical Precipitators
Form 9 Scrubber
Form 10 Fabric Filter
25. Attach as Appendix E to the application a list with description of all compliance monitoring devices and/or activities.
Include such things as make, model, type, size, capability, accuracy, calibration frequency, etc. for the devices and
monitoring frequency, outline of training program, level of certification required of inspectors, etc. for monitoring
activities.
26. Dispersion modeling will be required under two circumstances:
1. if the Executive Secretary determines that modeling is to be performed.
2. if the proposed emissions are in the range of values given in given in Table 1.
This requirement holds for new as well as modified sources. For modified sources, the values in Table 1. denote
emission increases. If the emission values are greater than values in Table 1, higher level modeling will be required.
Call the Planning Section at [phone] for additional information. The meteorological data to be used in the
modeling must be submitted to the Executive Secretary for review and approval before they are used in the dispersion
modeling exercise.
Table 1. Criteria For Screen Modeling (tons/year)
S02
NOx
PM10 fugitive
PM10 non-fugitive
CO*
HAP**
lead
40
40
5
15
100/250
varies
0.6
100 tons if one of the 28 source categories in UAC R307-1-3.6.5.B; 250 tons if not
Contact the Division of Air Quality Modeling Section.
27. For a description of a proper BACT proposal, see Form 1b.
28. Signature of authorized company agent.
29. Name of signing party.
30. Telephone number of signing party.
31 . Date of application.
ADDITIONAL INFORMATION MAY BE REQUIRED FOR SOME APPLICATIONS. If so. the reviewing engineer will
contact the individual listed in question number 2.
U:\aq\ENGINEER\GENERIC\Form01 .doc
Revised 5/10/06
4 of 4
Utah Division of Air Quality
New Source Review Section
Form 1d
Emissions Information
Company ___ C_he_v~r_o_n_P_i~p~e~L~in~e""-'-C~o.
Site/Source Hanna Station
Date 11/3/2008
Please print neatly or type all information requested. All information must be truthful, accurate and complete before
we can process your application. If you have any questions, call [phone] and ask to speak with a New
Source Review engineer. Written inquiries may be addressed to: Division of Air Quality, NSR Section, P.O. Box
144820, Salt Lake City, Utah 84114-4820.
a e T bl 1 P ropose d E .. m1ss1ons
Pollutant Permitted Emissions Emissions Increases Proposed Emissions
(tons/year) (tons/year) (tons/vear)
PM10
SO2
NOx
co
voe 12
Hazardous 0.3 Air Pollutants (total)
Hazardous Air
Pollutants (list
individually) (attach
additional sheet if
needed)
2,2,4-
Trimethylpentane 0.01
(isooctane)
Benzene 0.02
Biphenyl 0.00
Cresol (-m) 0.00
Ethylbenzene 0.01
Hexane (-n) 0.19
lsopropyl benzene 0.00 (cumene)
Naphthalene 0.01
Toluene 0.04
Xylenes (mixed 0.05 isomers)
other pollutants (list)
(attach additional
sheet if needed)
Page I of 4
Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
Table 2. Controlled and Uncontrolled Emissions
Pollutant Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year)
PM10
S02
NO,
co
voe 12
Hazardous Air Pollutants (total) 0.3
Hazardous Air Pollutants (list
individually) (attach additional sheet if
needed)
2,2,4-Trimethylpentane (isooctane) 0.01
Benzene 0.02
Biphenyl 0.00
Cresol (-m) 0.00
Ethylbenzene 0.01
Hexane (-n) 0.19
lsopropyl benzene ( cumene) 0.00
Naphthalene 0.01
Toluene 0.04
Xylenes (mixed isomers) 0.05
other pollutants (list) (attach
additional sheet if needed)
Page 2 of --1
Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
a e ouny mIssIons T bl 3 H I HAP E . .
Hazardous Air Pollutants (list individually) Maximum emission rate (lbs/hour)
2,2,4-Trimethylpentane (isooctane) 0.0019
Benzene 0.0053
Biphenyl 0.0005
Cresci (-m) 0.0008
Ethylbenzene 0.0026
Hexane (-nJ 0.0443
lsopropyl benzene (cumene) 0.0007
Naphthalene 0.0012
Toluene 0.0086
Xylenes (mixed isomers) 0.0125
Page 3 of 4
Table 1.
Table 2.
Table 3.
Utah Division of Air Quality
Approval Order Application
Form 1d
Emissions Information
Instructions
Fill out the table. Attach additional sheets if necessary. Provide potential emissions from your
entire facility in units of tons per year, expressed to at least two decimal places. Emissions of
individual Hazardous Air Pollutants may require more precision; contact a New Source Review
Engineer. If you do not now have an Approval Order and you are applying for your first
Approval Order, the emissions in "Existing Emissions" column will be zero and the "Emissions
Increases" will be equal to the "Proposed "Emissions. If you do have an Approval Order, the
emissions in the "Existing Emissions" column will be the emissions listed in your Approval
Order. All emissions should be those emissions occuring after any air pollution control devices.
Provide emissions that would result if you operated 24 hours per day, 8760 hours per year,
unless you are also proposing operating hour limits. If you are proposing operating hour limits,
state what these limits are and provide emissions based on these limits. Provide emissions that
would result from your potential production or potential raw material consumption, unless you
are also proposing production or raw material consumption limits. If you are proposing
production or raw material consumption limits, state what these limits are and provide emissions
based on these limits. Attach additional sheets with detailed calculations or stack testing
information showing how all of the above emission numbers were determined.
Fill out the table. Attach additional sheets if necessary. Provide potential emissions from your
entire facility in units of tons per year, expressed to at least two decimal places. Emissions of
individual Hazardous Air Pollutants may require more precision; contact a New Source Review
Engineer. The Hazardous Air Pollutants should be the same Hazardous Air Pollutants listed in
Table 1. The emissions in the "Controlled Emissions" column shoud be those emissions
occuring after any air pollution control devices. The emissions in the "Uncontrolled Emissions"
should be those emissions occuring before any air pollution control devices (in other words,
emissions that would result if you did not have any air pollution control devices at all. Provide
emissions that would result if you operated 24 hours per day, 8760 hours per year, unless you
are also proposing operating hour limits. If you are proposing operating hour limits, state what
these limits are and provide emissions based on these limits. Provide emissions that would
result from your potential production or potential raw material consumption, unless you are also
proposing production or raw material consumption limits. If you are proposing production or raw
material consumption limits, state what these limits are and provide emissions based on these
limits. Attach additional sheets with detailed calculations or stack testing information
showing how all of the above emission numbers were determined.
List all Hazardous Air Pollutants emitted by your facility. They should be the same Hazardous Air
Pollutants listed in tables 1 and 2. For each HAP provide its maximum emission rate in units of
pounds per hour. The emission rates should be those rates occuring after any air pollution
control devices. Attach additional sheets with detailed calculations or stack testing
information showing how all of the above emission numbers were determined.
Depending on other conditions unique to each facility, additional emissions information may be required.
f :laqlengineerlgenericl 1 d _ emisn. frm
Revised 1/23/03
Pagt' 4 of 4
Appendix A
Site Plan
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Appendix B
Flow Diagram
Process Flow Diagram
Pipeline from
Range ly Oil Field
Potent
Throu.
= 43,3
=15,80
ii
ay
ls/yr
+
Tank
T-520
. 60,000
hhl ..
CHEVRON PIPE LINE COMPANY
HANNA STATION
••
Fugiti ve Emi ss ions
-Valves, Fittings,
Pump Seals Tank
-Maintenance Emi ssions • • ! ' l
I
+ + • '! · Tanks Tanks Tank
~ T-510
\<
T-111 · ¥#TBD
., 60.000 ,, 40.000 60,000 .
hhl hhl bbl
-7
Pipeline to the
Salt Lake Refineries
Appendix C
Site Description
Chevron Pipe Line Company
Hanna Station
The Hanna Station is a pipeline pump station along the pipeline that transports crude oil from the
Rangely Oil Field to Salt Lake City for refining. The station is owned and operated by Chevron
Pipe Line Company. It is located in Duchesne County at 40700 West 7000 North, Hanna, Utah
84031 (4,472,294 N, 520,536 E, UTM, NAO 83, Zone 12). The facility operates continuously,
24 hours per day, 365 days per year. The facility is not manned; but employees make daily visits
to operate and maintain the station.
The pipeline transports crude, condensate, and black wax. The Hanna Station consists of four
breakout tanks used to relieve surges or temporarily store crude from the pipeline for reinjection
and continued transportation by pipeline to Salt Lake City. ln addition, there are two electric
pumps used to boost the pressure in the pipeline. The on-site evaporation pond is lined and is
used as a retention pond for stormwater runoffs: the drains for the pond are plugged. Sto1mwater
in the retention pond is not contaminated.
Sources of emission at the Hanna Station include the breakout tanks and piping components. The
anticipated throughput to the breakout tanks is 43 ,300 barrels per day ( 15.804.500 barrels per
year), consisting of 58% crude. 30% condensate, and 12% black wax condensate mixture.
Attached are the descriptions of the breakout tanks, report on Forni 20.
Tank I I 1 -Internal noating roof tank. 40,000 barrels, installed 1949
Tank 510 -External noating roof tank. 60.000 ba1Tel s. installed 1973
Tank 520 -External floating roof tank. 60,000 barrels. installed 1972
Tank #TBD -Internal floating roof tank, 60.000 barrels. proposed installation in 2009.
Other equipment on site includes:
• Two 30,000 BTU propane space heaters
• Two 500-gallon pressurized propane tanks used to run the space heaters.
• One 300-gallon solvent tank for parts cleaning. Stoddard solvent does not include HAPs.
VOC emissions are approximately 3 pounds.
Utah Division of Air Quality
New Source Review Section
Site/Source-=-: _....:H..:.;a=.;n:..:.;n:..:.;a::.i....;U:.T-=--------
Form 20 Date: ___ _,_1=0/_,_1=5/=2=00=8=------
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: Matrix Service 2. Identification number: TBD
3. Installation date: QrOQOSed 2008 4. Volume: 2,520,000 gallons
5. Inside tank diameter: 100 feel 6. Tank height: 43'-11" feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 199,136,700 gallons per year 12. Turnovers/yearly 79 Monthly Weekly
13. Average liquid height (feet) 43 14. Access hatch: EZl Yes o No Number 1
15. Type of Seals: 16. Deck Fittings:
a. Primary seals: Gauge float well 0Yes o No Number __ 1_
0 Mechanical shoe Gauge hatch/
□ Resilient filled sample well @Yes o No Number __ 1_
□ Liquid filled Roof drains □ Yes o No Number __
□ Vapor mounted Rim vents □ Yes o No Number
□ Liquid mounted Vacuum break Ill Yes □ No Number __ 1_
□ Flexible wiper Roof leg 0Yes □ No Number--1Q_
b. Secondary seal: Ladder well 0Yes D No Number __ 1_
Type: WiQer, rim-mounted Column well 0Yes D No Number __ 1_
Other:
17. Shell Characteristics: 18. Type of Construction:
Condition: New o Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction: Welded 0 Internal Floating Roof
Roof Type: Cone-Column SUQQOrted 0 External Floating Roof
Deck Construction: Welded 0 Other (please specify)
Deck Fitting Category: T~Qical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket o Venting □ Carbon Adsorption □ Thermal Oxidation □ Other:
I 20. Single Liquid Information I
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. ,____ Avg. Temperature:
Vapor Pressure: ,____ Vapor Pressure:
Liquid Molecular Weight Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form 20 -Organic Liquid Storage Tank
(Continued)
21 . Chemical Components Information
Chemical Name: ~ See TANKS Percent of Total Liquid Weight: _ printout in -Percent of Total Liquid Weight:
Molecular Weight: Appendix D. >--Molecular Weight:
Avg. Liquid Temperature: >--Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM ,o Lbs/hr __ Tans/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/hr __ Tons/yr voe 181 Lbs/hr 1.38 Tons/yr
HAPs 5.31 Lbs/hr {speciate) 0.04 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAO) at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid {psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or panel construction sizes and seam length
Deck fitting category; typical. controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f:\aq\ENGINEER\GENERIC\Forrn20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Site/Source,_: _...:.H.,,,a~n-"'n-'-"a::L..::U'--'T'------
Form 20 Date: ___ _,_10,,,_,/_,_1!e!5/ce:2-"-00"'"'8,c__ ___ _
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: Unknown 2. Identification number: Tank 111
3. Installation date: 1949 4. Volume: 1680000 gallons
5. Inside tank diameter: 80 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 3.5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 127,049,215 gallons per year 12. Turnovers/yearly 75.6 Monthly Weekly
13. Average liquid height (feet): 48 14. Access hatch: EZI Yes D No Number 1
15. Type of Seals: 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well 0Yes D No Number_1_
0 Mechanical shoe Gauge hatch/
D Resilient filled sample well IZl Yes D No Number_1_
D Liquid filled Roof drains □ Yes D No Number --
D Vapor mounted Rim vents □ Yes D No Number __
D Liquid mounted Vacuum break IZl Yes D No Number _1_
D Flexible wiper Roof leg IZ!Yes D No Number_l!_
b. Secondary seal: Ladder well IZl Yes D No Number _1_
Type: WiQer, rim-mounted Column well 0Yes D No Number _1_
Other:
17. Shell Characteristics: 18. Type of Construction:
Condition: Good □ Vertical Fixed Roof
Breather Vent Settings: □ Horizontal Fixed Roof
Tank Construction: Welded lil Internal Floating Roof
Roof Type: Cone -Column SuQQOrted □ External Floating Roof
Deck Construction: Welded □ Other (please specify)
Deck Fitting Category: Tl£Qical design standard APl-650
19. Additional Controls: N/A
□ Gas Blanket □ Venting □ Carbon Adsorption □ Thermal Oxidation D Other:
20. Single Liquid Information
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in -CAS Number:
Avg. Temperature: Appendix D. -Avg. Temperature:
Vapor Pressure: -Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form 20 -Organic liquid Storage Tank
(Continued)
21 . Chemical Components Information
,--Chemical Name: See TANKS Percent of Total Liquid Weight:_ printout in >--Percent of Total Liquid Weight:
Molecular Weight: Appendix D. -Molecular Weight:
Avg. Liquid Temperature: ,__ Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM10 Lbs/hr __ Tons/yr NO, Lbs/hr __ Tons/yr
so, Lbs/hr __ Tons/yr voe 123 Lbs/hr 0.94 Tons/yr
HAPs 3.29 Lbs/hr (speciate) 0.02 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help'
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi)
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f \aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Site/Source_: __ H~a_n_n~a~U_T ____ _
Form 20 Date: 10/15/2008
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: GATX 2. Identification number: Tank 510
3. Installation date: 1973 4. Volume: 2 520 000 gallons
5. Inside tank diameter: 95 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 3.5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11. Average throughput: 257,948,405 gallons per year 12. Turnovers/yearly 102.4Monthly __ Weekly_
13. Average liquid height (feet): 48 14. Access hatch: 0 Yes D No Number 1
15. Type of Seals: 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well IZl Yes D No Number_1_
0 Mechanical shoe Gauge hatch/
D Resilient filled sample well IZl Yes D No Number_1_
D Liquid filled Roof drains o Yes o No Number __
D Vapor mounted Rim vents IZI Yes o No Number_1_
D Liquid mounted Vacuum break IZl Yes D No Number_1_
D Flexible wiper Roof leg IZl Yes o No Number~
b. Secondary seal: Ladder well o Yes o No Number __
Type: Wi(!er, rim-mounted Column well o Yes D No Number __
Other: 1 unslotted guide-(!ole well
17. Shell Characteristics: 18. Type of Construction:
Condition: Good o Vertical Fixed Roof
Breather Vent Settings: o Horizontal Fixed Roof
Tank Construction: Welded o Internal Floating Roof
Roof Type: Pontoon 0 External Floating Roof
Deck Construction: Welded o Other (please specify)
Deck Fitting Category: Tt(!ical design standard APl-650
19. Additional Controls: N/A
o Gas Blanket o Venting o Carbon Adsorption o Thermal Oxidation D Other
20. Single Liquid Information
Liquid Name: See TANKS f---Liquid Name:
CAS Number printout in -CAS Number:
Avg. Temperature: Appendix D. f---Avg. Temperature:
Vapor Pressure: f---Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form 20 -Organic Liquid Storage Tank
(Continued)
21 . Chemical Components Information
,__ Chemical Name: See TANKS Percent of Total Liquid Weight:_ printout in '--Percent of Total Liquid Weight:
Molecular Weight: Appendix D. ~ Molecular Weight:
Avg. Liquid Temperature: ...._ Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM,o Lbs/hr __ Tons/yr NOx Lbs/hr __ Tons/yr
SOx Lbs/hr __ Tons/yr voe 299 Lbs/hr 2.27 Tons/yr
HAPs 8.23 Lbs/hr (speciate) 0.06 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAO) at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet.
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year. month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded. sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled. or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
f \aq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Utah Division of Air Quality
New Source Review Section
Site/Source.:..: _ _,H..:.:a:e,n..:.:n..:.:a:e.i...,U:e...T'---------
Form 20 Date: ___ ....:1-"'0'-'/1:..::5::..:/2:..:0:..::0:..::8 ____ _
Organic Liquid Storage Tank
Equipment
1. Tank manufacturer: GATX 2. Identification number: Tank 520
3. Installation date: 1972 4. Volume: 2,520 000 gallons
5. Inside tank diameter: 95 feet 6. Tank height: 48 feet
7. True vapor pressure of liquid: 0-14 psia 8. Reid vapor pressure of liquid: 5 psi
9. Outside color of tank: White 10. Maximum storage temperature: 200 OF
11 . Average throughput: 79,654,680 gallons per year 12. Turnovers/yearly 31.6 Monthly __ Weekly_
13. Average liquid height (feet): 48 14. Access hatch: EZI Yes D No Number 1
15. Type of Seals 16. Deck Fittings: Unknown, used TANKS default
a. Primary seals: Gauge float well 0Yes D No Number_1_
[Z) Mechanical shoe Gauge hatch/
□ Resilient filled sample well IZI Yes o No Number_1_
0 Liquid filled Roof drains o Yes o No Number __
D Vapor mounted Rim vents Ill Yes o No Number_1_
0 Liquid mounted Vacuum break IZl Yes D No Number_1_
0 Flexible wiper Roof leg IZI Yes D No Number~
b. Secondary seal: Ladder well o Yes o No Number __
Type: Wiper, rim-mounted Column well o Yes D No Number --
Other: 1 unslotted guide-pole well
17. Shell Characteristics: 18. Type of Construction:
Condition: Good o Vertical Fixed Roof
Breather Vent Settings: o Horizontal Fixed Roof
Tank Construction: Welded o Internal Floating Roof
Roof Type: Pontoon 0 External Floating Roof
Deck Construction: Welded o Other (please specify)
Deck Fitting Category: T:-ipical design standard APl-650
19. Additional Controls: N/A
o Gas Blanket :::i Venting o Carbon Adsorption o Thermal Oxidation o Other:
20. Single Liquid Information
Liquid Name: See TANKS -Liquid Name:
CAS Number: printout in CAS Number: -Avg. Temperature: Appendix D. -Avg. Temperature:
Vapor Pressure: -Vapor Pressure:
Liquid Molecular Weight: Liquid Molecular Weight:
Page 1 of 2
Chemical Name: -
Form 20 -Organic Liquid Storage Tank
(Continued)
21 . Chemical Components Information
Chemical Name: -See TANKS Percent of Total Liquid Weight:_ printout in -Percent of Total Liquid Weight:
Molecular Weight: Appendix D. -Molecular Weight:
Avg. Liquid Temperature: -Avg. Liquid Temperature:
Vapor Pressure: Vapor Pressure:
Emissions Calculations (PTE)
22. Calculated emissions for this device:
PM10 Lbs/hr __ Tons/yr NO. Lbs/hr __ Tons/yr
so. Lbs/hr __ Tons/yr voe 237 Lbs/hr 1.81 Tons/yr
HAPs 8.18 Lbs/hr (speciate) 0.06 Tons/yr (speciate)
Submit calculations as an appendix. Provide manufacturer's Material Safety Data Sheets for products being stored.
See Appendix D for emission calculations.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help'
1. Indicate the tank manufacturer's name.
2. Supply the equipment identification number that will appear on the tank.
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallons or barrels.
5. Specify the inside tank diameter in feet
6. Specify the tank height in feet.
7. Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the liquid (psi).
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will reach during storage (degrees Fahrenheit).
11 . Indicate average annual throughput (gallons).
12. Specify how many times the tank will be emptied and refilled per year, month or week.
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has access hatches and the number.
15. Indicate what type of seals the tank has.
16. Indicate what type of deck fittings are installed.
17. Specify condition of the tank, also include the following:
Breather vent settings in (psig) for fixed roof tanks
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded. sheet or panel construction sizes and seam length
Deck fitting category; typical, controlled, or detail
18. Indicate the type of tank construction.
19. Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21 . Provide information on chemicals being stored, add additional sheets as necessary.
22. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your
calculations.
flaq\ENGINEER\GENERIC\Form20.doc
revised 9/1 /06
Page 2 of 2
Appendix D
Emission Estimate
CHEVRON PIPE LINE COMPANY
HANNA STATION
EMISSIONS SUMMARY· 2008 POTENTIAL
1011412008
Annual Annual Hourly
CAS Equipment Maintenance Emissions Emissions Emissions Erv•
Pollutant Number Unit Tanks' Fugitive2 Fugitive 1 lb/yr ton/yr lb/hr lb/hr Hourly Em ission > ETV?
voe lb 12,788.25 11,244.25 500.00 24,532.50 12.27
HAPs
2.2.4-Trimethylpentane (isooctane) 540-84-1 lb 8.01 7.98 0.36 16.35 0.01 0,0019 NA No, air modeling not required
Benzene 71-43-2 lb 26.36 19 00 0,85 46.21 0.02 0.0053 0.027 No, air modeling not required
Biphenyl 92-52-4 lb 1.65 2.70 0.12 4.47 0 00 0.0005 0.064 No, air modeling not required
Cresol (-m) 108-39-4 lb 2.54 4.16 0.19 6.89 0.00 0.0008 1.13 No, air modeling not required
Ethylbenzene 100-41-4 lb 9.01 13.27 0.59 22.87 0.01 0,0026 22.1 No, air modeling not required
Hexane (-n) 110-54-3 lb 250.40 132.01 5.87 388.27 0.19 0.0443 9 No. air modeling not required
lsopropyl benzene (cumene) 98-82-8 lb 2.30 3.60 0.16 6.06 0.00 0.0007 12.5 No. air modeling not required
Naphthalene 91-20-3 lb 3.92 6.41 0.29 10.61 0.01 0,0012 2,7 No, air modeling not required
Toluene 108-88-3 lb 33.41 40.48 1.80 75,68 0,04 0.0086 3.8 No, air modeling not required
Xvlenes (mixed isomers) 1330-20-7 lb 42.64 63 .87 2.84 109.34 0.05 0.0125 22.1 No, air modeling not required
TOTAL HAPs lb 380.24 293.47 13,05 0.34
TOTAL voes ton 6.39 5.62 0.25 12.27
1. RVP 3.5 and RVP 5.0 used for TANKS.
2. Equipment fugitives are totals that include pumps seals. valves. flanges. and drains.
3. Maintenance includes one tank cleaning.
4. Emission threshold value, minimum. vertically restricted/fugitive releases <20 m from property boundary.
Utah Division of Air Quality. downloaded 9/24/2008. http://www.airquality.utah.gov/Planning/Modeting/NSR_Permit_Modeling/Modeling¾20Guidelinesl2007 ACGIH-TLVs.xls
ETV = emission threshold value
HAP = hazardous air pollutant
NA= not available
CHEVRON PIPE LINE COMPANY
HANNA STATION
INPUTS for EMISSIONS ESTIMATE -2008 POTENTIAL
10/14/2008
Fugitive Count
Source Number
Of Units
Drains (open-ended lines) 4
Valves 106
Flanges 35
Pump Seals 18
Others 10
Tank Configuration
Height Tank Volume
Tank# Tank Type Primary Seals Secondary Seals Roof Diameter (ft) (ft) (bbl) (gal)
111 Internal Floater Mechanical Shoe Wiper. Rim-mounted Cone 80 48 40.000 1,680,000
510 External Floater Mechanical Shoe Wiper. Rim-mounted Pontoon 95 48 60,000 2,520,000
520 External Floater Mechanical Shoe Wiper. Rim-mounted Pontoon 95 48 60,000 2,520.000
New Internal Floater Mechanical Shoe Wiper. Rim-mounted Cone 100 43.92 60.000 2,520,000
Potential Tank Throughput
Potential Annual Throughput (bbls)
15,804,500
RVP' Fraction' TP (bbl)
Rangely Crude 2.42 58% 9.166.610
Condensate 4.67 30% 4.741.350
Black Wax Condensate Mix 4.08 12% 1.896,540
Total 100% 15,804,500
1.,ruae u11
RVP used in Year
Tank# Product TP (bbl) TP (gal) Turnover TANKS) Installed
111 Rangely Crude (33%) 3.024.981 127.049.215 75.6 3.5 1949 )"'3 -84{'~·1,1.,"ZD ...._
510 Rangely Crude (67%) 6,141 .629 257,948.405 102.4 3.5 1973 ' I <
520 Black Wax Condensate Mix 1.896.540 79.654.680 31.6 5.0 1972 -,0., <.,,;-\ I \.,i!,O <
New Condensate 4.741.350 199.136.700 79.0 5.0 TBD I qq \ ~ ·1oc> D
Total 15,804,500 663,789,000 I f _,.
'Reid vapor pressure (RVP) was determined in laboratory tests.
2Fractional throughput based on design maximum daily throughput of 43.300 bbl/day. 13.000 bbl/day of condensate. 25.000
bbl/day of Rangely crude, and 5.300 bbl/day of black wax condensate mix.
TP = throughput
RVP = Reid vapor pressure
Conversions
bbls = 42 gals
CHEVRON PIPE LINE COMPANY
HANNA ST A TION
FUGITIVE EMISSIONS -2008 POTENTIAL
10/14/2008
FuQitive VOCs
Emisson Emisson
Number of Factors1 Factors Emissions2 Emissions
Description Units (kq/hr/source l (lb/hr/source l (lb/vrl (ton/vrl
Valves 106 2.50E-03 5.50E-03 5,107.08 2.55
Pump Seals 18 1.30E-02 2.86E-02 4,509.65 2.25
Others 10 7.50E-03 1.65E-02 1,445.40 0.72
Connectors 0 2.1 0E-04 4.62E-04 0.00 0.00
Flanges 35 1.10E-04 2.42E-04 74.20 0.04
Open ended lines (drains) 4 1.40E-03 3.08E-03 107.92 0.05
Equipment Fugitives 11 ,244.25 5.62
Maintenance Fugitives3 500.00 0.25
TOTAL FUGITIVES, voes 11,744.25 5.87
1. Emission tractors from "Protocol for Equipment Leak Emission Estimates", EPA-453/R-95-017, November 1995.
Table 2-4 Oil and Gas Production. emission factors for light oil service.
2. Emissions=(# of units)(Emission Factor)(24 hr/day)(365 day/yr)
3. Maintenance includes one tank cleaning.
Conversion: 1 kg = 2.2 lb; 1 ton = 2000 lb
FuQitive HAPs
Equipment Maintenance
Weight Fugitive Fugitive Total
Pollutant Fraction1 (lb/yr) (lb/yr) (lb/yr)
voes 11 ,244.25 500.00 11,744.25
2,2,4-Trimethylpentane (isooctane) 0.00071 7.98 0.36 8.34
Benzene 0.00169 19.00 0.85 19.85
Biphenyl 0.00024 2.70 0.12 2.82
Cresol (-m) 0.00037 4.16 0.19 4.35
Ethyl benzene 0.00118 13.27 0.59 13.86
Hexane (-n) 0.01174 132 01 5.87 137.88
lsopropyl benzene 0.00032 3.60 0.16 3.76
Naphthalene 0.00057 6.41 0.29 6.69
Toluene 0.0036 40.48 1.80 42.28
Xylenes (mixed isomers) 0.00568 63.87 2.84 66.71
TOTAL FUGITIVE HAPs (lbs.) 293.47 13.05 306.52
1. Weight fraction from API Publication 4723, Nov 2002 (PERF data}; Crude Oil.
CHEVRON PIPE LINE COMPANY
HANNA STATION
TANK EMISSIONS -2008 POTENTIAL
10/14/2008
Description GAS Unit Tank #TBD Tank 111 Tank 510 Tank 520 Total Comment
Annual Throughput qal 199.136,700 127,049,215 257,948.405 79,654,680 663.789,000 15,804,500 bbl throughput
2.2.4-Trimethylpentane (isooctane) 00540-84-1 lb 1.84 1.25 2.74 2.19 8.01
Benzene 00071-43-2 lb 5.50 3.32 8.60 8.95 26.36
Biphenyl 00092-52-4 lb 0.46 0.37 0.62 0.19 1.65
Cresci (-m) 00108-39-4 lb 0.71 0.57 0.96 0.30 2.54
Ethylbenzene 00100-41-4 lb 2.41 1.86 3.33 1.42 9.01
Hexane (-n) 00110-54-3 lb 48.41 26.36 78.88 96.75 250.40
lsopropyl benzene 00098-82-8 lb 0.63 0.50 0.86 0.31 2.30
Naphthalene 00091-20-3 lb 1.10 0.88 1.48 0.46 3.92
Toluene 00108-88-3 lb 8.25 5.96 11.83 7.36 33.41
Xylenes (mixed isomers) 01330-20-7 lb 11.48 8.92 15.80 6.44 42.64
Total Tank voes lb/yr 2,755.29 1,873.79 4,547 70 3,611.47 12,78825
lb/hr 181.17 123.21 299.03 237.47 840.87
ton/yr 138 0.94 2.27 1.81 6.39
Total Annual Tank HAPs (lb) lb/yr 80.80 49.98 125.09 124.37 380.24
lb/hr 5.31 3.29 8.23 8.18 25.00
ton/yr 0.04 0.02 0.06 0.06 0.19
1. Results from TANKS 4.09d. ran 10/14/2008.
2. Speciation of HAPs used in TANKS based on API Publication 4723, Nov 2002 (PERF data).
HAP = hazardous air pollutant
TRI = toxic release inventory
2007 ACGIH Threshold Limit Values (TLVS). Toxic Screening Levels (TSLs) and Emission Threshold Values (ETVs)
The purpose of this document is to serve as aid to NSR Engineers. Consultants. and the General Public in their interpretation of the applicability
of UACR307-410-5 when preparing or reviewing a Notice of Intent.
UACR307-410-5 requires any source submitting a NOi. which proposes to increa se emission of HAP. to use Table 2 in the rule to determine
whether or not a dispersion modeling analysis of each pollutant is required as part of a complete NOi. If new emissions of the HAP
(expressed in lb/hr) exceeds the emission threshold value. dispersion modeling is required.
When selecting the proper Emission Threshold Factor. the folowing release scenario should be determined as follows.
"Vertically Restricted Emissions Release" means the release of an air contaminant through a stack or opening whose flow is directed
in a downward or horizontal direction due to the alignment of the opening or a physical obstruction placed beyond the opening .
or at a height which is less than 1.3 times the height of an adjacent building or structure. as measured from ground level.
"Vertically Unrestricted Emissions Release" means the release of an air contaminant through a stack or opening whose flow is directed upward
without any physical obstruction placed beyond the opening , and at a height which is at least 1.3 times the height of an adjacent building or structure,
as measured from ground level.
The lb/yr and TPY values calculated for chronic and carcinogenic HAP below are based on the assumption that the
source operates continuously (8760 hr/yr).
Acute values are express in lb/hr only. and emission limits or emission levels for acute HAP should not be expressed or calculated
in lb/hr or TPY. This is due to the nature of the chemical itself, whereby very short term exposure to high concentrations of the HAP
will result in immediate adverse health effects in the exposed individual.
Therefore. when evaluating acute HAP for the determination of modeling requirements, ALWAYS evaluate it based
on the maximum potential emission rate possible for that process. Do not back-calculate the lb/hr emission rate from
the sources proposed pounds or tons per year emission level listed in the NOi.
The range of emission threshold values are:
Acute
Chronic
Carcinogenic
Minimum ETF - 0.038
Minimum ETF - 0.051
Minimum ETF -0.017
For each type of HAP, there is a minimum and maximum emissions threshold factor (ETF). They are :
Maximum ETF -0.310
Maximum ETF -0.368
Maximum ETF -0.123
Using these values . we are able to calculate the minimum emission rate for each type of HAP such that any source operating with a
proposed lb/hr emission level less than this value would not be required to perform a dispersion modeling analysis for this NOi process.
Similarly. using these values . we are able to calculate the maximum emission rate for each type of HAP such that any source operating
with a proposed lb/hr emission level greater than this values would inevitably be required to perform a dispersion modeling analysis
for this NOi process.
However. if the source's proposed emission rate is greater than the minimum emission rate . but less than the maximum emission
rate listed in the table below. the reviewing engineer will have to review the addition information required to be submitted under
R307-410-4 to determine if modeling is required (ie, pollutant release type and distance to property boundary).
A listing of Tl Vs, TSLs. and minimum and maximum ETVs are shown in the first half of the table below.
The full range of ETVs for all ETFs are listed in the second half of this document.
Utah Division of Air Quality , downloaded 9/24/2008.
http 1/www .airq uality. utah.gov/Plann1ng/Modeling/N SR_ Perm1t_Modeling/Modeling¾20G uidelines/200 7 ACG I H-TL Vs. xis
2007 ACGIH Threshold Limit Values (TLVS). Toxic Screening Levels (TSLs) and Emission Threshold Values (ETVs)
Show
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
ACUTE
Hazardous
Air Pollutants
CARCINOGENIC
Hazardous
Air Pollulanls
Benzene (induding benzene for gasol
CHRONIC
Hazardous
Air Pollutants
Biphenyl
Cresols/Cresylic acid
Cumene
Ethyl benzene
Hexane
Naphthalene
Toluene
Xylenes (isomers and mixture)
ACUTE
Hazardous
Air Pollutants
CARCINOGENIC
Hazardous
Air Pollutants
Benzene (including benzene for gasol
CHRONIC
Hazardous
Air Pollutants
Bi phenyl
Cresols/Cresyhc acid
Cumene
Ethyl benzene
Hexane
Naphlhalene
Toluene
Xylenes (isomers and mixlure)
Health
Classification
Health
Class1ficat1on
Al Care.
Health
Classification
Chronic
Chrohic
Chronic
Chronic
Chronic
Chronic
Chronic
Chronic
Heallh
Classification
Heallh
Classif1cat1on
A1 Care.
Health
Classification
Chronic
Chronic
Chronic
Chrome
Chronic
Chronic
Chronic
Chronic
Utah Division of Air Quality. downloaded 9/24/2008;
Toxic Em1ss1on Rate Below
Screenmg Vvt11ch Modeling
Applicable TLV-Ce1l1ng TLV-Ce1hng Molecular Levels Would Never Be Triggered
Factor 1-Hour 1-Hour Weighl (TSLs) Under UAC307-410-5
Safety (ug/m3) (ppm) 1-Hour Average "ETF=0.038 I
ug/m3 lb/hr lb/day I TPY
Toxic Emission Rate Below
Screening \Nh1ch Modeling
Applicable TLV-TWA TLV-TWA ~olecular We1gt Levels Would Never Be Triggered
Factor 8-Hour 8-Hour (TSLs) Under UAC307-410-5
Safety (ugim3) (ppm) 24-Hour Average •ETF=0.017 l•Continious operations
ug/m3 lb/hr I lb/yr I TPY
30 1,597 0.5 78. 11 53 0.027 I 238 I 0.12
Toxic Emission Rate Below
Screening IM\ich Modeling
Applicable LV-TWA(ug/m TLV-TWA ~olecular Weigt Levels Would Never Be Triggered
Factor 8-Hour 8-Hour (TSLs) Under UAC307-410-5
Safety (ppm) 24-Hour AVerage •ETF=0.051 ·continious operations
ug/m3 lb/hr lb/yr TPY
30 1,261 0 154.20 42 0.064 564 0.28
30 22.115 5.00 108.14 737 1.13 9.880 4.94
30 245,787 50.00 120.19 8,193 12.5 109,808 54,9
30 434,192 100,00 106.16 14.473 22.1 193,980 97.0
30 176.237 50.00 86.18 5,875 9.0 78,736 39.4
30 52.429 10.00 128.19 1.748 2.7 23,423 11,7
30 75,362 20.00 92. 13 2.512 3.8 33.669 16.8
30 434,192 100,00 106.16 14,473 22.1 193,980 97.0
Acute Emission Threshold Values (in lb/hr)
Distance to Property Boundary and Emission Threshold Factors
Vertically Restncted/Fug1live Releases Vertically Unrestricted Releases
<20 m 20-50 m 50-100 m >100 m <SO m 50-100 m >100 m
0.038 0.051 0.092 0.180 0.154 0.224 0.310
Carcinogenic Emission Threshold Values (in lb/hr)
Distance to Property Boundary and Emission Threshold Factors
Vertically Restricled/Fug1tive Releases Vertically Unrestricted Releases
<20 m 20-50 m 50-100 m >100 m <50 m 50-100 m >100 m
0.017 0.022 0.041 0.090 0.066 0.081 0.123
0.0272 0.0351 0,0655 0.1438 0.1054 0.1294 0.1965
Chronic Emission Threshold Values (In lb/hr)
Distance to Property Boundary and Emission Threshold Factors
Vertically Restricted/Fugitive Releases Vertically unrestricted Releases
<20 m 20-50 m 50-100 m >100 m <50m so-100 m >100 m
0,051 0.066 0.123 0.269 0.198 0.224 0,368
0.06 0.08 0.16 0.34 0.25 0.28 0.46
1 13 1.46 2.72 5,95 4.38 4.95 8.14
t2.54 16.22 30.23 66.12 48.67 55.06 90.45
22.14 28.66 53.41 116.80 85.97 97.26 159.78
8.99 1 t.63 21 .68 47.4 t 34.80 39,48 64.86
2.67 3.46 6.45 t4.10 10.38 11 .74 19.29
3.84 4.97 9.27 20.27 14.92 16.88 27.73
2214 28.66 53.41 116.80 85.97 97.26 159.78
http· //www.airq uality. utah. gov/Planning/Modeling/NS R _Perm it_Modeling/Modeling ¾20G uidelines/2007 ACG I H-TL Vs. xis
Emission Rate Above
\J\tlich Modeling
Would Always Be Triggered
Under UAC307-410-5
"ETF•0.310
lb/hr lb/day I TPY
Emission Rate Above
VVhich Modeling
Would Always Be Tnggered
Under UAC307-410-5
'ETF=0.123 •continious operations
lb/hr lb/yr I TPY
0.20 1721 I 0.86
Emission Rat• Above
IM\lch Modeling
Would Always Be Triggered
Under UAC307-410-5
•ETF=0.368 •continious operations
lb/hr lb/yr TPY
0.46 4,066 2.0
8.14 71,290 35.6
90.4 792,340 396.2
159.8 1,399,697 700
64.9 568.132 284
19.3 169,016 84.5
27.7 242,943 121
159.8 1,399,697 700
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Identification
User Identification:
City:
State:
Company:
Type of Tank
Description:
Tank Dimensions
Diameter (ft):
Volume (gallons)
Turnovers:
Self Supp. Roof? (yin):
No. of Columns:
Eff. Col. Diam. (ft):
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade
Shell Condition
Roof Color/Shade
Roof Condition
Rim-Seal System
Primary Seal:
Secondary Seal
Deck Characteristics
Deck Fitting Category:
Deck Type:
Deck Fitting/Status
Tank lndentification and Physical Characteristics
Hanna Tank #TBD -2008 Potential
Hanna
Utah
Chevron Pipe Line Company
Internal Floating Roof Tank
Condensate
N
Light Rust
White/White
Good
White/White
Good
Mechanical Shoe
Rim-mounted
Typical
Welded
100.00
2,520,000.00
79.02
1.00
1.00
-----------------·-"''""'"'"---------------------~·--·····-··~·-,"··
Access Hatch (24-in. Diam.)/Unbolted Cover. Ungasketed
Automatic Gauge Float Welt/Unbolted Cover. Ungasketed
Column Well (24-in. Diam.)/Built-Up Col.-Sliding Cover. Ungask.
Ladder Well (36-in. Diam.)/Sliding Cover. Ungasketed
Roof Leg or Hanger Well/Adjustable
Sample Pipe or Well (24-in. Diam )/Slit Fabric Seal 10% Open
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation. Gask.
Meterological Data used in Emissions Calculations: Salt Lake City. Utah (Avg Atmospheric Pressure = 12.64 psia)
Quantity
1
1
6
1
32
1
1
Page I of 13
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank #TBD -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
Liquid
Daily Liquid Surf Bulk Vapor L1qu1d
Temperature (deg F) Temp Vapor Pressure (ps,a) Mal Mass
Mixture/Component Monlh Avg. Min Max (deg F) Avg M,n Max Weight. Fract.
Crude oil (RVP 5) All 53 92 47 99 59 86 51 98 2 5505 NIA NIA so 0000
1 2 4-Tnmethy1henzene 0 0160 NIA NIA 120 1900 0.0023
2 2 4. Tnmethylpentane (1sooctane) 0 4987 NIA NIA 114.2300 0 0007
Benzene 0 9843 NIA NIA 78.1100 0.0017
81nhenyl 0.0008 NIA NIA 154.2000 0.0002
Cresol (-m) 0.0010 NIA NIA 108 1000 0.0004
E thylbenzene 0.0876 NIA NIA 106.1700 0.0012
Hexane (-n) 1.6300 NIA NIA 86. 1700 0.0117
lsopropyl benzene 0.0382 NIA NIA 120.2000 0.0003
Naphthalene 0.0019 NIA NIA 128.2000 0.0006
Toluene 0.2725 NIA NIA 92.1300 0.0036
Uniden11f1ed Components 2.6610 NIA NIA 49.2054 0.9716
Xylenes (mixed ,somers) 0.0728 NIA NIA 106.1700 0.0057
]
Page 2 of 13
Vapor
Mass Mol. Basis for Vapor Pressure
Fracl. Weight Calculations
_, __ ,_,_
207.00 Op11on 4 RVP=5
0 0001 120.19 Option 2 A=7.04383. B= 1573.267. C=208.56
0.0006 114 23 Option 2 A=6.8118, 8=1257,84, C=220.74
0.0027 78.11 Option 2 A=6.905, 6=1211.033. C=220.79
0.0000 154.20 Option 1. VPS0 = .0007 VP60 = .00099
0.0000 108.10 Option 2 A=7.508. 6=1856.36. C=199.07
0.0002 106.17 Op11on 2 A=6.975, 6=1424.255. C=213.21
0.0311 86.17 Option 2. A=6.876, 8=1171.17. C=224.41
0.0000 120.20 Option 2 A=6.93666. 8=1460.793, C=207.78
0.0000 128.20 Option 2. A=7.3729, 6=1968.36, C=222.61
0.0016 92.13 Op11on 2· A=6.954. 8=1344.8, C=219.48
0.9631 214.40
0.0007 106.17 Option 2 A=7.009. 8=1462.266. C=215,11
I 0/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report ~ Summary Format
Individual Tank Emission Totals
Hanna Tank #TBD • 2008 Potential -Internal Floating Roof Tank
Hanna , Utah
II Losses(lbs)
!components II Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
!crude oil (RVP 5) II 67.5111 1.923.7311 764 0411
I 1.2.4-Trimethylbenzene II 0.0011 4.4811 o.05I1
I Biphenyl II o ooll 0.4611 0.0011
I Cresol (-m) II o.ooll 0.7111 0.0011
I lsopropyl benzene II o.ooll 0.62II 0.0211
I Ethylbenzene II 0.0111 2.2111 0.1311
Hexane (-n) II 2.1011 22.5811 23.7311
Naphthalene II o.ooll 11011 0.0011
Toluene II 0 1111 6.93 11 1.2211
Xylenes (mixed isomers) II o 05JI 10.9311 0.5111
2.2.4-Trimethylpentane (isooctane) II 0 0411 1.3711 0.4411
Benzene II 0,1811 3.2511 2.0611
Unidentified Components II 65 0311 1,869 0411 735.8911
Page 3 of 13
Deck Seam Lossll Total Emissions!
o.ooll 2,755.291
0.0011 4.531
o.ool l 0.461
o.ool l 0,711
o.ooll 0.631
0.0011 2.41 I
0.0011 48.411
o ooJI 1.101
0.0011 8 251
0.0011 11.481
o.ooll 1.841
o.ooll 5,501
0.0011 2,669.961
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Identification
User Identification.
City
State:
Company:
Type of Tank:
Description:
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Self Supp. Roof? (yin):
No. of Columns:
Eff. Col. Diam. (ft):
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade :
Shell Condition
Roof Color/Shade:
Roof Condition:
Rim-Seal System
Primary Seal:
Secondary Seal
Deck Characteristics
Deck Fitting Category:
Deck Type:
Deck Fitting/Status
Tank lndentification and Physical Characteristics
Hanna Tank 111 -2008 Potential
Hanna
Utah
Chevron Pipe Line Company
Internal Floating Roof Tank
Crude Oil
N
Light Rust
White/White
Good
White/White
Good
Mechanical Shoe
Rim-mounted
Typical
Welded
80.00
1,680,000.00
75.62
1.00
1.00
Access Hatch (24-in. Diam .)/Unboited Cover. Ungasketed
Automatic Gauge Float Well/Unbolted Cover. Ungasketed
Column Well (24-in. Diam.)/Buiit-Up Coi.-Sliding Cover. Ungask.
Ladder Well (36-in. Diam.)/Sliding Cover. Ungasketed
Roof Leg or Hanger Well/Adjustable
Sample Pipe or Well (24-in. Diam.)/Slit Fabric Seal 10% Open
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation. Gask.
Meterologicai Data used in Emissions Calculations: Salt Lake City. Utah (Avg Atmospheric Pressure = 12.64 psia)
Quantity
1
1
1
1
24
1
1
Page 4 of 13
10/14/2008
T i\N KS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 111 -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
L1qu1d
Daily L1qu1d Surf Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure {ps1a) Mal. Mass
Mixture/Component Month Avg Min Max (deg F) Avg. Mm Max. Weight. Fract
-·•·------· -··-··--··-. ----·-
Crude 0 11 (RVP 3.51 All 53.92 47 99 59 86 51 98 1.5477 NIA NIA 60.0000
1.2 4-Tr1methylbenzene 00160 NIA NIA 120.1900 0 0023
2 2 d-Trimethylpen!ane (1!;ooctane) 0.4987 NIA NIA 114.2300 0.0007
Benzene 0.9843 NIA NIA 78, 1100 0.0017
81phenyl 0.0008 NIA NIA 154.2000 0.0002
Cresol (-m) 0.0010 NIA NIA 108,1000 0.0004
Ethylbenzene 0.0876 NIA NIA 106.1700 0.0012
Hexane (-n) 1.6300 NIA NIA 86. 1700 0.0117
lsopropyl benzene 0.0382 NIA NIA 120.2000 0.0003
Naphthalene 0.0019 NIA NIA 128.2000 0.0006
Toluene 0.2725 NIA NIA 92. 1300 0.0036
Unidentified Components 1.5727 NIA NIA 59.4493 0.9716
Xylenes (mixed ,somers) 0.0728 NIA NIA 106.1700 0.0057
Page 5 of 13
Vapor
Mass Mol. Basis for Vapor Pressure
Fract. Weight Calculations
·---.. ----
120.00 Option 4 RVP=3.5
0.0000 120.19 Option 2 A=7.04383. 6=1573.267. C=208.56
0.0005 114.23 Option 2 A=6.8118. 6=1257.84. C=220.74
0.0021 78.1 I Option 2 A=G.905. B= 1211.033. C=220.79
0.0000 154.20 Option 1. VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2· A=7.508. 6=1856.36. C=199.07
0.0001 106.17 Option 2 A=6.975. 8=1424.255. C=213.21
0.0247 86.17 Option 2· A=6.876. 8=1171.17, C=224.41
0.0000 120.20 Option 2· A=6.93666. 8=1460.793. C=207.78
0.0000 128.20 Option 2 A=7.3729, 8=1968.36, C=222.61
0.0013 92.13 Option 2. A=6.954. 8=1344.8, C=219.48
0.9707 120.93
0.0005 106.17 Option 2 A=7.009, 8=1462.266, C=215.11
I 0/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 111 -2008 Potential -Internal Floating Roof Tank
Hanna, Utah
II Losses(lbs)
I components II Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
Crude Oil (RVP 3.5) II 37.5911 1.537.9711 298.2311
1,2.4-Trimethylbenzene 0.0011 3 sail 0.0111
Biphenyl 0.0011 0 3711 o.ooll
Cresci (-m) 0.0011 0.5711 0.0011
lsopropyl benzene 0.0011 0.4911 o.ooll
Ethylbenzene 0.0111 1.a1 II 0.0411
I Hexane (-n) 0.9311 18.0611 7.3711
I Naphthalene o.ooll 0.8811 o.ooll
I Toluene o 0511 5 5411 0.3811
I Xylenes (mixed isomers) 0 0211 8 7411 0.16II
I 2. 2 .4-T rimethylpentane (isooctane) 11 0 0211 1 0911 0 1411
I Benzene II o.oall 2 6011 0.6411
I Unidentified Components II 36.4911 1.494 2511 289.4811
Page 6 of 13
Deck Seam Lossll Total Emissions!
0.0011 1,873.791
0.0011 3.601
0.0011 0.371
0.0011 0.571
0.0011 o.5ol
0.0011 1.861
0.0011 26.361
o ooll 0.881
o.ooll 5.961
0.0011 8.921
o.ooll 1.251
0.0011 3.321
o.ooll 1,820.211
10/14/2008
TAN KS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Identification
User Identification:
City
State:
Company:
Type of Tank:
Description:
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Characteristics
Type:
Fitting Category
Tank lndentification and Physical Characteristics
Hanna Tank 510 -2008 Potential
Hanna
Utah
Chevron Pipe Line Company
External Floating Roof Tank
Crude Oil
Light Rust
White/White
Good
Pontoon
Typical
95.00
2.520,000.00
102.36
Tank Construction and Rim-Seal System
Construction: Welded
Primary Seal: Mechanical Shoe
Secondary Seal Rim-mounted
Deck Fitting/Status Quantity -----···-·· ............. ·-.... ----.... ----
Access Hatch (24-in. Diam.)/Bolted Cover, Gasketed
........ _ ... ---·-· ....... ____ ......... _.... . .. . . .. . 1
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation. Gask.
Unslotted Guide-Pole Well/Ungasketed Sliding Cover
Gauge-Hatch/Sample Well (8-in. Diam.)/Weighted Mech. Actuation. Gask.
Roof Leg (3-in. Diameter)/Adjustable. Pontoon Area. Ungasketed
Roof Leg (3-in. Diameter)/Adjustable. Center Area. Ungasketed
Rim Vent (6-in. Diameter)/Weighted Mech. Actuation. Gask.
Meterological Data used in Emissions Calculations: Salt Lake City. Utah (Avg Atmospheric Pressure = 12.64 psia)
1
1
1
1
17
16
1
Page 7 of 13
10/1 4/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 510 -2008 Potential -External Floating Roof Tank
Hanna, Utah
L1qu1d
Daily Uqu1d Surf. Bulk Vapor Liquid
Temperature (deg F) Ternp Vapor Pressure (ps1a) Mol. Mass
M1xture/Componen1 Month Avg Min. Max (deg F) Avg. Min Max Weight Fract.
--------O•••-• ---·-----·--------· ---··---
Crude 0 1 (RVP 3 5) All 5] 92 47 99 59.86 51 98 1 5477 NIA NIA 60 0000
1.2 4-Tnmethylbenzene 0.0160 NIA NIA 120 1900 0.0023
2.2 4-Trimethytpentane (1sooctane) 0 4987 NIA NIA 114.2300 0.0007
Benzene 0 9843 NIA NIA 781100 0.0017
81phenyl 0.0008 NIA NIA 154 2000 0.0002
Cresol (-m) 0.0010 NIA NIA 108.1000 0.0004
Elhylbenzene 0 0876 NIA NIA 106 1700 0.0012
Hexane (-r,) 1.6300 NIA NIA 86 1700 0.0117
I sopropyl benzene 0 0382 NIA NIA 120 2000 0.0003
Naphthalene 0.0019 NIA NIA 128 2000 0.0006
T ol11ene 0 2725 NIA NIA 92 1300 0.0036
Unidentified Components 1.5727 NIA NIA 59.4493 0.9716
Xylenes (rn1xed isomers) 0.0728 NIA NIA 106.1700 0.0057
Page 8 of 13
Vapor
Mass Mol. Basis for Vapor Pressure
Fract. Weight Calculations ·-----
120.00 Option 4 RVP=3.5
0.0000 120.19 Option 2 A=7.04383 8=1573.267. C=208.56
0 0005 114.23 Option 2· A=6.8118. 8=1257.84. C=220.74
0.0021 78.11 Option 2 A=G.905. 8=12 t 1033. C=220.79
0.0000 154.20 Option 1. VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2 A=7.508. 6=1856.36. C=199.07
0.0001 106.17 Option 2 A=6.975. 8=1424.255. C=213.21
0.0247 86. 17 Option 2 A=6.876. 8=1171.17. C=224.41
0 0000 120.20 Option 2 A=6.93666. 8=1460.793. C=207.78
0.0000 128.20 Option 2 A=7 3729. 8=1968.36. C=222.61
0.0013 92.13 Option 2 A=6.954 8=1 344.8. C=219.48
0.9707 120.93
0.0005 106.17 Option 2 A=7.009 B= 1462.266. C=215.11
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 510 -2008 Potential -External Floating Roof Tank
Hanna, Utah
I II Losses(lbs)
I components Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
!crude Oil (RVP 3.5) 306.7711 2 597 0611 1,650.0111
I 1.2.4-Trimethylbenzene 0.01 11 6 0511 o.08II
I Biphenyl 0.0011 0.62II o.ooll
I Cresci (-m) o.ooll 0 9611 0.0011
I lsopropyl benzene I 0.0011 0.8311 0.0311
I Ethylbenzene II 0,0411 3 0611 0.2211
Hexane (-n) II 7.5911 30.4911 40.8011
Naphthalene II 0.0011 1.4811 o.ooll
Toluene II 0 3911 9.3511 2.0911
Xylenes (mixed isomers) II 0.16II 14.7511 0.8811
2.2.4-Trimethylpentane (isooctane) II 0.1411 1,8411 0,7611
Benzene II 0.6611 4.3911 3.5511
Unidentified Components II 297.nll 2,523,2211 1.601 .6111
Deck Seam Lossll
0.0011
0.0011
o.ooll
0.0011
o.ooll
0.0011
0.0011
o.ooll
0.0011
0.0011
o.ooll
0.0011
0.0011
J
Page 9 of 13
Total Emissions!
4,553.841
6.151
0.621
0.961
0.861
3.331
78.881
1.481
11.831
15.801
2.741
8.601
4,422.601
10/14/2008
TANKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Tank lndentification and Physical Characteristics
Identification
User ldentificalion:
City:
Hanna Tank 520 -2008 Potential
Hanna
Utah State
Company:
Type of Tank:
Description:
Chevron Pipe Line Company
External Floating Roof Tank
Black Wax Condensate Mix
Tank Dimensions
Diameter (ft):
Volume (gallons):
Turnovers:
Paint Characteristics
Internal Shell Condition:
Shell Color/Shade:
Shell Condition
Roof Characteristics
Type
Fitting Category
Light Rust
White/White
Good
Pontoon
Typical
Tank Construction and Rim-Seal System
Construction: Welded
Primary Seal: Mechanical Shoe
Secondary Seal Rim-mounted
Deck Fitting/Status
Access Hatch (24-in. Diam.)/Bolted Cover, Gasketed
Automatic Gauge Float Well/Unbolted Cover, Ungasketed
95.00
2.520.000.00
31.61
Vacuum Breaker (10-in. Diam.)/Weighted Mech. Actuation, Gask.
Unslotted Guide-Pole Well/Ungasketed Sliding Cover
Gauge-Hatch/Sample Well (8-in. Diam.)/Weighted Mech. Actuation, Gask.
Roof Leg (3-in. Diameter)/Adjustable. Pontoon Area. Ungasketed
Roof Leg (3-in. Diameter)/Adjustable. Center Area . Ungasketed
Rim Vent (6-in. Diameter)/Weighted Mech. Actuation. Gask.
Meterological Data used in Emissions Calculations: Salt Lake City. Utah (Avg Atmospheric Pressure = 12 .64 psia)
•
Quantity
1
1
1
1
1
17
16
1
Page 10 of 13
I 0/14/2008
T J\NKS 4.0 Report
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Hanna Tank 520 -2008 Potential -External Floating Roof Tank
Hanna, Utah
L1qu1d
Daily L1qu1d Surf. Bulk Vapor Liquid
Temperature (deg F) Temp Vapor Pressure (ps1a) Mel. Mass
M1xture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract.
~-·------·• ·-----··-•-··· ··-·--· ---•·------· -· -------~---
Crude 01I (RVP 5) All 53.92 47.99 59.86 51.98 2.5505 NIA NIA 50.0000
1.2 4. Trimethylbenzene 0.0160 NIA NIA 120.1900 0.0023
2.2.4-Tmnethylpentane (1sooctane) 0.4987 NIA NIA 114,2300 0.0007
Benzene 0.9843 NIA NIA 78.1100 0.0017
81phenyl 0.0008 NIA NIA 154.2000 0.0002
Cresci (-m) 0.0010 NIA NIA 108.1000 0.0004
E thylbenzene 0.0876 NIA NIA 106,1700 0.0012
Hexane (-n) 1.6300 NIA NIA 86, 1700 0.0117
1sopropyl benzene 0.0382 NIA NIA 120.2000 0.0003
Naphthalene 0.0019 NIA NIA 128.2000 0.0006
Toluene 0.2725 NIA NIA 92. 1300 0.0036
Un1dentlf1ed Components 2.6610 NIA NIA 49,2054 0.9716
Xylenes (mixed isomers) 0.0728 NIA NIA 106.1700 0,0057
Page 11 of 13
Vapor
Mass Mel. Basis for Vapor Pressure
Fract. Weight Calculations
207.00 Option 4 · RVP=5
0.0001 120.19 Option 2. A=7.04383. 8=1573.267, C=208.56
0,0006 114.23 Option 2· A=6.8118, 8=1257.84, C•220.74
0.0027 78.11 Option 2: A=6.905, 8=1211.033, C•220.79
0,0000 154.20 Option 1 VP50 = .0007 VP60 = .00099
0.0000 108.10 Option 2: A=7.508. 8=1856.36. C=199.07
0.0002 106.17 Option 2. A=6.975, 8=1424.255. C•213.21
0.0311 86.17 Option 2: A=6.876. 8=1171.17. C=224.41
0.0000 120.20 Option 2: A=6.93666, 8=1460.793. C=207.78
0.0000 128.20 Option 2: A=7.3729. 8=1968.36, C=222.61
0.0016 92.13 Option 2: A=6,954, 8=1344.8, C=219.48
0.9631 214.40
0.0007 106,17 Option 2: A=7,009, B= 1462.266, C=215.11
I 0/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Hanna Tank 520 -2008 Potential -External Floating Roof Tank
Hanna, Utah
II Losses(lbs)
I components II Rim Seal Lossll Withdraw! Lossll Deck Fitting Lossll
!crude oil (RVP 5) II 440.7811 801.9711 2,370.7611
I 1.2.4-Trimethylbenzene II 0.0311 1,8711 0 1411
I Biphenyl II 0.0011 0.19 11 o ooll
I Cresci (•m) II 0.0011 0.30 11 0.0011
I lsopropyl benzene II 0.0111 02611 o.05II
I Ethyl benzene I 0.0711 o.95II 0.4011
I Hexane (-n) 13 6911 9.4211 73.6411
I Naphthalene o ooll 0.4611 o ooll
I Toluene 0 7011 2 8911 3.7711
I Xylenes (mixed isomers) 0.30 11 4.5611 1.5911
I 2.2.4-Trimethylpentane (isooctane) 0.25 11 0.5711 1.3611
I Benzene 1,1911 1.3611 6.4011
I Unidentified Components 424.5411 779.1711 2,283.4011
Page 12 of 13
Deck Seam Lossll Total Emissions!
0.0011 3.613.51 I
0.0011 2.041
o ooll 0.191
0.0011 0.301
0.0011 o.31 I
0.0011 1.421
0.0011 96.751
o ooll 0.461
o.ooll 7.361
o.ooll 6.441
o.ooll 2.191
0.0011 8,951
0.0011 3,487.111
10/14/2008
J
TANKS 4.0 Report Page 13 of 13
TANKS 4.0.9d
Emissions Report -Summary Format
Total Emissions Summaries -All Tanks in Report
Emissions Report for: Annual
Tank Identification Losses (lbs)
Hanna Tank #TBD -2008 Potential Chevron Pipe Line Company Internal Floating Roof Tank Hanna. Utah 2,755.29
Hanna Tank 111 -2008 Potential Chevron Pipe Line Company Internal Floating Roof Tank Hanna. Utah 1,873.79
Hanna Tank 51 O -2008 Potential Chevron Pipe Line Company External Floating Roof Tank Hanna. Utah 4,553.84
Hanna Tank 520 -2008 Potential Chevron Pipe Line Company External Floating Roof Tank Hanna. Utah 3,613.51
Total Emissions for all Tanks: 12,79643
10/14/2008
TANKS 4.0 Report
Identification
User Identification:
City:
Stale:
Company:
Type of Tank:
Description:
Tank Dimensions
Shell Length (ft):
Diameter (ft):
Volume (gallons):
Turnovers:
Net Throughput(gal/yr):
Is Tank Heated (y/n):
Is Tank Underground (y/n):
Paint Characteristics
Shell Color/Shade:
Shell Condition
Breather Vent Settings
Vacuum Settings (psig):
Pressure Settings (psig)
TANKS 4.0.9d
Emissions Report -Summary Format
Tank lndentification and Physical Characteristics
Solvent Tank
Hanna
Utah
Chevron Pipe Line Company
Horizontal Tank
Solvent
N
N
Aluminum/Specular
Good
5.00
6.00
300.00
1.00
300.00
-0.03
0.03
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure= 12.64 psia)
Page 1 of 4
10/14/2008
TANKS 4.0 Report
Solvent Tank -Horizontal Tank
Hanna, Utah
Mixture/Component Month
Solvent All
Daily Liquid Surf.
Temperature (deg F)
Avg. Mm. Max.
57.19 49.02 65.36
TANKS 4.0.9d
Emissions Report -Summary Format
Liquid Contents of Storage Tank
Liquid
Bulk Vapor Liquid
Temp Vapor Pressure (psia) Mol. Mass
(deg F) Avg. Min. Max. Weig,!. Fract.
53.30 0.1000 0.1000 0.1000 80.0000
Page 2 of 4
Vapor
Mass Mol. Basis fa
Fract. Weight Calculal
120.00
10/14/2008
TANKS 4.0 Report
Emissions Report for: Annual
Solvent Tank -Horizontal Tank
Hanna, Utah
I components
!solvent
II
II
II
TANKS 4.0.9d
Emissions Report -Summary Format
Individual Tank Emission Totals
Losses(lbs) I
Working Lossll Breathing Lossll Total Emissions!
0.0611 2.7311 2781
Page 3 of 4
10/1 4/2008
TANKS 4.0 Report Page 4 of 4
10/14/2008
Appendix E
BACT Analysis
CHEVRON PIPE LINE CO.
HANNA STATION
1.0 BACKGROUND
BACT Analvsis
The Utah Division of Air Quality (DAQ) air permit regulations [UAC R307-401-5(2)(d) and
R307-401-8(l)(a)] require any new or modified source seeking an approval order must
consider the Best Available Control Technology (BACT). BACT is to be applied to new and
modified emission units and is to be determined on a case-by-case basis, with consideration
given to energy impacts, technical feasibility, environmental impacts, and economic impacts.
This section presents a BACT analysis for the new and existing emission units that are part of
the Chevron Pipe Line Company Hanna Station.
For the Hanna Station. volatile organic compounds (VOCs) are the only pollutants emitted
into the atmosphere. For purposes of prevention of significant deterioration (PSD) analysis,
each project-affected source that emits VOCs must be evaluated to determine BACT. A
BACT analysis is being perfonned for each BACT emission applicable unit that is either
existing or will be installed at the facility and will have an increase of VOC emissions.
To complete a detailed BACT analysis. the United States Environmental Protection Agency
(U.S. EPA) top-down BACT methodology is used to analyze available options and then
select an appropriate control technology. To utilize the top-down approach, commercially
available control options for each applicable pollutant are identified. Technically infeasible
alternatives are then dismissed, and the remaining control options are analyzed and ranked
according to control effecti\'eness. To select a BACT option, the following items are
evaluated: energy impacts. environmental impacts, economic impacts, cost effectiveness, and
site-specific factors. The control technology selected provides the most stringent level of
control without causing adverse economic, energy, or environn1ental impacts. Generally, the
cost effectiveness parameter is stated as either total or incremental annualized dollar cost per
ton of pollutant abated.
An extensive review of the U.S. EPA RACT/BACT/LAER Clearinghouse (RBLC) database
has been performed for similar sources to identify emission control strategies relevant to the
proposed project. An extensive review of the RBLC defined the range of potentially
applicable emission control applications.
For some Hanna Station sources. a strict top-down analysis is not necessary to identify
appropriate BACT. In these instances, accepted emission control technology alternatives are
identified. Of these, feasible alternatives may then be evaluated in comparison with accepted
BACT practices as described in the RBLC or in published BACT guidelines. Jn no case is
the recommended BACT less stringent than the controls required under New Source
Pe1fonnance Standards (NSPS) and National Emission Standards for Hazardous Air
CHEVRON PIPE LINE CO.
HANNA STATION BACT Analysis
Pollutants (NESHAP) regulations. The federal requirements are considered a "floor" for
BACT considerations.
For the Hanna Station, the BACT-applicable sources are listed below in Table 1.
Table l
Hanna Station BACT-Applicable Sources
Source ID Source Description Estimated Increase (tpy)
PSD Pollutant -VOC
T-111 IFR Tank 0.94
T-510 EFR Tank 2.27
T-520 EFR Tank 1.81
T-TBD 1FR Tank 1.38
Equipment Fugitives 5.62
Table 2 presents a summary of proposed BACT for the emission sources proposed to be
installed as part of the Hanna Station. Details of the BACT analysis are presented in the
remainder of this section.
Table 2
Summary of Proposed BACT
Source Description Pollutant
Internal Floating Roo f voe Tanks
External Floating Roof voe Tanks
'
Process Fugitive voe
BACT = Best .1\\"ailable Control Technology
LDAR = Leak Detection and Repair
VOC = Volatile Organic Compound
2.0 TOP-DOWN BACT APPROACH
Most Feasible BACT Selected
• Internal Floating Roof
• Compliance with regulatory programs
• Ex ternal Floating Roof
• Compliance with regulatory programs .
• Compliance with LOAR program .
• Leak definition more stringent than regulation .
BACT is defined in the Clean Air Act as "a11 emissions limit based on the maximum degree
of emissio11s reduction for each pol/1110111 ... 11·/,ic/1 the permitting authority determines. 011 a
case by case basis. 1aki11g into acco11111 energv. e11rironme11tal. and economic impacts and
2
CHEVRON PIPE LINE CO.
HANNA STATION BACT Ana1Vsis
other costs, is achievable for such .facility through th e application of production processes
and available methods, systems, and techniques ... ". Two key aspects of the definition are
worthy of notice:
• BACT includes and, in fact, focuses on "production processes" along with add-on
controls.
• BACT was intended to be a case-by-case evaluation, implying individual case
evaluations and decisions, not rigid, pre-set guidelines.
The top-down BACT approach starts with the most stringent (or top) technology that has
been applied to similar emissions units. A source of control technology information is the
RBLC database. The RBLC is an EPA-sponsored database that li sts previously EPA-
approved BACT determinations. The top control technology is either accepted as BACT or
rejected based on technical or economic infeasibility. If the top control technology is
rejected as BACT, the next most stringent control technology is either accepted as BACT or
rejected. The top-down approach is continued until a control technology, which is found to
be both technically and economically feasible, is accepted as BACT.
3.0 BACT APPLICABILITY
Each of the proposed units to be installed as part of the Hanna Station that generate any VOC
emi ssions \\·ill require BACT review. Existing emission units require a BACT analysis as
\\'ell.
4.0 STORAGE TANKS
Four storage tanks (T-111 , T-510, T-520 and T-TBD) produce VOC emissions; therefore, an
analysis will be conducted to establish what constitutes BACT. Resultant VOC emissions
from storage tank s occur through two processes defined as working and breathing losses.
The existing. storage tanks T-111 , T-510, and T-520; and the proposed tank T-TBD are/will
be equipped with fl oating roofs as required by 40 CFR 60.l 12b(a), NSPS Subpa11 Kb.
Working loss emissions are mostly attributed to the loading and unloading of a tank, at which
time the hydrocarbon vapor located in the tank headspace is displaced. Working loss
emissions generally account for the large majority of emissions from storage tanks.
Breathing loss emissions occur from the cycli c diurnal temperature changes. Because the
equilibrium pressure of the vapor and liquid phases (vapor pressure) is a function of
3
CHEVRON PIPE LINE CO.
HANNA STATION BACT Analvsis
temperature, this heating and cooling cycle allows for VOC displacement through the
expansion and contraction of the headspace.
4.1 Storage Tank voe BACT Analysis
The historical accepted VOC control practice for storage tanks consists of design measures to
minimize the hydrocarbon vapor space displacement.
4.1.1 Step 1 -Identify Potential Control Technologies
The first step in a BACT analysis is to identify all available control technologies.
Review of Historical BACT Determinations
The RBLC BACT databases contain numerous BACT determinations for the control of VOC
emissions from storage tanks. Review of the RBLC provides an indication of prior BACT
determinations for storage tanks. A summary of this review appears in Table A-1.
Chevron Pipe Line also reviewed the BACT detenninations for storage tanks at the proposed
Arizona Clean Fuels, LLC Greenfield refinery and the proposed Hyperion Greenfield
refinery in South Dakota as a means to supplement the RBLC search results. Some of these
determinations include:
• Fixed roof with a closed vent system and vapor capture system
• Internal floating roof with dual seals and inert gas blanketing
• External floating roof with dual rim seals
• Thermal oxidation
Option 1 -Internal floating roof tank with appropriate sea) design
An internal floating roof tank incorporates a roof structure that floats on the liquid surface
exerting pressure on the vapor phase, thus decreasing the volume of vapor available to emit.
The floating roof would also uses an appropriate seal design to allow a minimal amount of
vapor from exiting as rim losses. In addition to a roof floating on the liquid surface an
additional fixed roof is also constructed atop the storage tank further limiting the vapor
displacement to the atmosphere.
4
CHEVRON PIPE LINE CO.
HANNA STATION
Option 2 -External floating roof with appropriate seal design
BACT Analvsis
This technology is similar to that listed in Option 1 ; however, there is no fixed roof atop the
floating roof to further minimize vapor displacement to the atmosphere.
Option 3 -Work Practices required by regulatory programs
Storage tanks are regulated under 40 eFR 60 (NSPS). These regulations require that the
facility comply with both vapor pressure and design requirements listed for storage tanks.
The requirements are specified in various ranges of vapor pressure and capacities.
Option 4 -Thermal Oxidation
Thermal oxidation combusts voe streams with a control efficiency of greater than 95%, and
can be used for control of any voe-containing stream, including storage tanks. Thermal
oxidation is used to process vented voe streams by using an incineration unit or flaring
device. While voes are destroyed in this process, other combustion emissions are created
and must be accounted for in the emission inventory for the refinery.
4.1.2 Step 2 -Eliminate Technically Infeasible Options
The second step in the BAeT analysis is to eliminate any technically infeasible control
technologies. Each control technology identified in Step I is technically feasible.
4.1.3 Step 3 -Ranking of Remaining Control Technologies by Control Effectiveness
The third step in the BAeT analysis is to rank the remaining technically feasible control
technologies in order of control effectiveness. Table 3 shows that ranking.
5
CHEVRON PIPE LINE CO.
HANNA STATION
Table 3
BACT Analvsis
Ranking of Remaining Control Options for VOCs from Storage Tanks
Rank Control Type Control Efficiency
I Thermal Oxidation >95%
2a Internal fl oating roof Baseline
2b External floating roof Baseline
Uncontrolled em1ss10ns are not listed because industry standards prevent storing vo latile
organic liquids in ta nks w ithout a roof.
4.1.4 Step 4 -Evaluation of the Most Effective Controls
The fourth step in th e BACT analysis is lo evaluate the most effective control technologies
not eliminated due to technical infeasibility.
Thermal Oxidati on
The feasibility of adding a th ermal ox idation to the storage tanks was considered. Based on
standard cost estimation techniques and uncontro ll ed emissions, the cost of installing and
operating thennal oxidation would be approx imately $106,000 -$256,000 per ton of VOC to
be removed per tank, which exceeds the ty pical cost thresholds used to verify the cost-
effecti veness of a control option {$5 ,000). The cost information and data used to support the
cost effectiveness detern1ination is included in Table 4. This hi gh cost is mostl y attributed to
the low VOC emissions from each tank and the operational cost associated with th e thermal
ox idizer. In addi tion to the hi gh cost, thenn al oxidizers do emit other criteria pollutants
resulting from combustion such as NOx, CO. PM 10, etc. Due to the economic . energy, and
environmental impacts. the thermal oxidizer is being rejected as BACT.
6
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·03 3NI'l 3dld NONA3H::>
CHEVRON PIPE LINE CO.
HANNA STATION
Floating Roof
BACT Analysis
Installing a floating roof design is within the economic budget for the facility. It is more cost
effective to initially construct a floating roof tank than to convert a fixed roof tank to a
floating roof tank. The tanks at the Hanna Station tanks will have floating roofs as required
by 40 CFR 60.1 I 2b(a).
4.1.5 Step 5 -Selection of voe BACT for Storage Tanks
Because Chevron Pipe Line is interested in controlling em1ss10ns m a manner that is
environmentally effective, cost effective and in compliance with 40 CFR 60. l l 2b(a),
Chevron proposes that the installation and operation of floating roof tanks subject to NSPS
requirements be considered BACT for voe for the Storage Tanks. Tanks T-520 and T-510
are equipped with external floating roof tanks, and Tanks T-111 and T-TBD is/will be
equipped with internal floating roof tanks.
4.1.6 Practically Enforceable BACT for Storage Tanks
Development of emission limit to reflect selected control technology
VOC emissions from the Storage Tanks were calculated using the EPA TANKS 4.09d
software. The estimated voe emissions associated with storage tanks T-111 , T-520. T-510,
and T-TBD are 0.41 , 1.39, 1.53, and 0.58 tons VOC per year respectively. This emissions
estimate is based upon the current/expected design and emissions calculations from EPA
TANKS 4.09d. The facility will ensure that the selected BAeT is properly installed,
operated. and the selected work practice standards are properly implemented.
Compliance Monitoring
The facility will comply with applicable NSPS Subpart Kb requirements for the storage
tanks. All monitoring. recordkeeping, and reporting will be done in compliance with NSPS
requirements.
5.0 PROCESS FUGITIVES
The Hanna Station uses many piping components to distribute the liquid materials (mostly
crude oil) between tanks and pipeline. These piping components are potential sources of
8
CHEVRON PIPE LINE CO.
HANNA STATION BACT AnalVsis
VOC em1ss1ons due to leaking equipment. VOC em1ss1ons from those components are
mostly related to potential leakage from valves, flanges, and pump seals.
It is important to Chevron that these piping components are effectively monitored to decrease
emissions as much as possible. The piping components carry products which contain VOCs
that will increase emissions if the component leaks. Therefore, a Chevron has employed a
Leak Detection and Repair (LDAR) Program to minimize leaks.
5.1 Fugitive voe BACT Analysis
Common strategies for controlling VOC em1ss1ons from equipment leaks are based on
LDAR work practices rather than by the traditional emission limits and control devices. The
LDAR program currently implemented at the Hanna Station incorporates a vigorous
monitoring schedule involving visual inspection (via olfactory inspections) to monitor and
control emissions from piping components. Chevron Pipe Line proposes to comply with the
most stringent requirements for LDAR.
5.1.1 Step 1 -Identify Potential Control Technologies
The first step in a BACT analysis is to identify all available control technologies.
Review of Historical BACT Determinations
The RBLC database review provides an indication of historical BACT determinations for
fugitive emissions. The RBLC database contains numerous BACT determinations for the
control of VOC fugitive emissions. A summary of this review can be found in Table B-1.
As demonstrated in a review of the RBLC, the primary control strategy across the board for
fugitive VOC emissions is an effective LDAR program. This is true for a facility with
fugitive emission limits both on the high and low ends. The requirements for such programs
are defined in the Federal regulations.
Chevron Pipe Line also reviewed the BACT determinations for equipment leaks at the
proposed Arizona Clean Fuels, LLC Greenfield Refinery and the proposed Hyperion
Greenfield Refinery in South Dakota as a means to supplement the RBLC search results.
Some of these determinations include:
9
CHEVRON PIPE LINE CO.
HANNA STATION BACY Analvsis
• Adopt more-stringent leak detection definitions consistent with TRNCC 28 MlD
emission reduction option.
• Limited implementation of seal-less magnetic drive pumps and bellows-seal valves.
• Implement a LDAR program consistent with 40 CFR 63 -Subparts Il and CC.
Option I -Implementation of applicable regulatory programs
The RBLC analysis demonstrates that the primary control strategy for control of fugitive
VOC emissions is an effective LDAR program. An effective LDAR program includes a
suitable definition of a '·leaky"" component threshold concentration and a detailed strategy for
repairing leaks once they have been identified. For the Hanna Station, NESHAP -Subpai1 R
is applicable. NESHAP -Subpart R does not specify a leak definition since the only
monitoring that is required is that performed by visual inspections. The Hanna Station
proposes to comply with NESHAP -Subpart R. A summary of applicable regulatory
requirements and proposed BACT can be found in Table 5.
10
CHEVRON PIPE LINE CO.
HANNA STATION BACT Analysis
Table 5
Summary of Proposed BACT and Applicable Equipment Leak Requirements
Component Proposed NESHAP
BACT Subpart R
Valves-Light Liquid No visual No visual
leaks leaks
Valves-Heavy Liquid No visual No visual
leaks leaks
Valves-Gas No visual No visual
leaks leaks
Pumps-Light Liquid No visual No visual
leaks leaks
Pumps-Heavy Liquid No visual No \·isual
leaks leaks
Pressure Relief Val\'e-No \'isual No \·isual
Gas leaks leaks
Pressure Relief Valve-No \'isual No \'isual
Liquid leaks leaks
Light Liquid No \'isual No \'isual
Connectors leaks leaks
VOC Compressors No\ isual No \·isual
leaks leaks
Closed Vent Systems No \·isual No \'isual
leaks leaks
Option 2 -Implementation of enhanced regulatory program
As discussed in Option 1, Hanna Station will comply with the applicable requirements of
NESHAP -Subpart R. The enhancement of applicable regulatory programs will not be
necessary since there are no other applicable equipment leak provisions applicable to the
Hanna Station. Furthermore. the facility transpo11slstores crude oil and petroleum refinery
standards to not apply to the facility.
5.1.2 Step 2 -Eliminate Technically Infeasible Options
The second step in the BACT analysis is 10 eliminate any technically infeasible control
technologies. The implementation of applicable regulatory programs as described in Step 1
is technically feasible.
I I
CHEVRON PIPE LINE CO.
HANNA STATION BACT Analysis
5.1.3 Step 3 -Ranking of Remaining Control Technologies by Control Effectiveness
The third step in the BACT analysis is to rank the remaining technically infeasible control
technologies in order of control effectiveness. The most effective of the identified control
technologies is a combination of the identified options. Specifically, this includes an LDAR
program with work practices relative to NESHAP -Subpart R.
5.1.4 Step 4 -Evaluation of the Most Effective Controls
The fourth step in the BACT analysis is to evaluate the most effective control technologies
not eliminated due to technical infeasibility. The most effective identified control strategy
for fugitive VOC emissions is proposed as BACT. This system will not result in any adverse
energy or environmental impacts. Accordingly. no evaluation of alternative control options
is warranted.
5.1.5 Step 5 -Selection of voe BACT for Fugitive Emissions
Chevron proposes that the implementation of an LDAR program in compliance with
NESHAP -Subpart R be considered BACT for fugiti ve emissions of VOC. The LDAR
program, as identified in the five step process. wi ll reduce emissions through determination
of leaks identified by visual inspections. Compliance with ESHAP -Subpart R will reduce
emissions of any regulated pollutant within the transport streams.
Practically Enforceable BACT.fiJr F11giti1·e Emissions
Development of Emission Limit to Reflect Selected Control Technology
VOC emissions from the fugitive emission sources were calculated using emission factors
taken from the Protocol for Equipment Leak Emission Estimates, EPA-453/R-95-017, Table
2-2 and Refinery Average Emission Factors and the Equipment Leaks Fugitives guidance
document from the TCEQ (dated ovember 1995).
The following regulations from 40 CFR 60 (NSPS), and 40 CFR 63 (NESHAP) were
reviewed in relation to fugitive emissions:
• NESHAP Subpart R -National Emission Standards for Gasoline Distribution
Facilities (Bulk Gasoline Terminals & Pipeline Breakout Stations)
12
CHEVRON PIPE LINE CO.
HANNA STATION BACY AnalVsis
• NESHAP Subpart CC (not applicable) -National Emission Standards for Hazardous
Air Pollutants from Petroleum Refineries
• NSPS Subpart GGG (not applicable) -Standards of Performance for Equipment
Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After January 4, 1983, and on or Before November 7, 2006
• NSPS Subpart GGGa (not applicable) -Standards of Performance for Equipment
Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After November 7, 2006
• NSPS Subpart VY (not applicable) -Standards of Perfonnance for Equipment Leaks
of VOC in the Synthetic Organic Chemicals Manufacturing Industry for Which
Construction. Rec onstruction, or Modification Commenced After January 5, 198 I ,
and on or Before November 7. 2006
• NSPS Subpart VVa (not applicable) -Standards of Performance for Equipment
Leaks of VOC in the Synthetic Organic Chemicals Manufacturing Industry for Which
Construction. Reconstructi on, or Modification Commenced After November 7, 2006
Of the regulations reviewed. it was determined that the Hanna Station is only subject to
NESHAP -Subpart R. Therefore. the Harurn Station must comply with the requirements of
an LOAR program structured according to the requirements of NESHAP -Subpart R.
LOAR program compliance is enforceable through evaluation of LOAR monitoring and
repair documentati on. Visual inspections will be used to effectively identify leaks, and
LOAR documentation will be maintained through LEAKOAS. LDAR program compliance
will be continuous.
Compliance Monitoring
The Chevron Pipe Line Hanna Station is proposing compliance with the enhanced LOAR
program as specified in Table 5 of this permit application. The facility has implemented an
LDAR Program to assure compliance with NESHAP requirements for the facility. All
monitoring, recordkeeping.. and reporting will be done in compliance with the applicable
equipment leak requirements.
13
CHEVRON PIPE LINE CO.
HANNA STATION
Tahle A-I
Summary of VOC BA CT Determinations (p er EPA 's RBLC) for Storage Tanks
FACILITY PERMIT TI-IRU TJ-IRU EMIS EM.IS
FACILITY NAME STATE DATE PROCESS NAME PUT l'llT CONTROL DESCRJPTION LIMIT LIMIT!
UNIT 1 UNIT
Flll·.1. OIi. Kl:NAI Rl:FINl:RY AK ,12112nnn S I0I{/\(d'. ·1 ;\NKS NONI: INl)JC'.<\Tl:D
Fl 11:1. (lll. KEN,\! Rl:FIN l'RY AK 312112()()() STOR/\Cil' TANKS NONI: INDICA JED
Tl IE F.MISSIONS FROM (iROI JI' A
STORACil: TANKS MUST Bl:
C'OL.I .ECTFll BY A VAPOR
COMl'RESS!ON SYSTl:M AND
AR II.ONA Cl.l:AN Al. 4/14/2/lOS CiROl ll'A ROI ITFI) TO Tl II' lff.l·INl:RY
I'I 11:1.S YI JM.<\ STORM ii: TANKS Fl 11:1. CiAS SYSTEM NO
l:MISSJnNs ARE l'l:RMITTED TO
BE RFl.l'ASFD INTO Tl IE AIR
l'XCFPT FOR F()I Jll'MENT
1.I:AKS
Tl IE EM ISSIONS FROM (iROLJI' A
STORA( ii'. TANKS Ml 1ST 11E
COI.I..ECTEIJ HY A VAPOR
COMPRESSION SYSTEM AND
ARl/,ONA CLEAN Al. 4/14/2005 CiROIJP A ROI JTED TO TIIE RFFINERY
Fl JFI.S Yl JMA STORA<iE TANKS FUEi . (i/\S SYSTEM. NO
EMISSIONS ARE l'ERMITTED TO
[lE REI.EASED INTO Tl IE AIR
E:XCEPT f'OR EOIJll'MENT
LEAKS.
THE TANKS ARE REQI IIRED TO
/\RWlN/\ CI.E/\N /\7. 4/1-1/2005 CiROIII' ll flE l IN llER PRESSURE SO Tl !AT
Fl 11:1.S YI JM/\ STOR/\CiE TANKS NO EMISSIONS /\RI' EMITTED TO
Tl IE ATMOS I'! JERE
FIXED ROOF TANK WITI I
AR I/ONA Cl FAN Srn lR WATER INTERN/\! FJ.O;\TINCi ROOF
Fl 11:1 S Yl IM.-\ /\I, 4/14/2()(), TAN K I !FAil Sl'/\CI: ROI IJ'J'IJ TO/\
C;\RllON /\JJSORl'TION SYSTEM.
BACT Analysis
POLLUTANT COMPLIANCE NOTES
KEL:P RECORDS READILY AVAILABLE
SI IOWINCi Tl IE DIMENSIONS AND
CAl'ACITIES OF Tl IE STORAGE VESSU5
KEEP RECORDS READILY A VAILABI.E
SI IOWIN<i Tl II.: DIMENSIONS AND
CAl'ACITIF.S OF TIIF. STORAGE VESSELS
Tl !ERE IS NO NUMERICAL EM ISSIONS
LIMIT FOR GROUP A TANKS SINCE Tl IE
EM ISSIONS MIJST BE COLLECTED AND
NOT EMITTED INTO THE ATMOSPHERE.
TIIERE IS NO NUMERICAL EMISSIONS
LIMIT FOR GROlJI' A TANKS SINCE Tl-IE
EMISSIONS MUST BE COLLECTED AND
NOT EMITTED INTO THE A TMOSPI-IERE.
THE TANKS ARE REQUIRED TO BE
UNDER PRESSURE SO THAT NO
EMISSIONS ARE EMITTED TO THE
ATMOS Pl JERE.
FIXED ROOF TANK WITH INTERNAL
f'LO/\TINCi ROOF. IIEAD SPACE ROUTED
TO A CARBON ADSORPTION SYSTEM.
14
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA 's RBLC) for Storage Tanks
FACILITY PERMIT THRU TURU EMlS EMlS
F'ACILITY NAME STATE DATE PROCESS NAME PlJT PUT CONTROL DESCRIPTION LIMIT : LIM.IT I
UNIT I UNIT
RIT INFRY MACT REQIJJRES
PONCA CITY OK 7/l /2002 TANKS VARIES CERTAIN CONTROL DEVICES
RITINl:RY WI IICI I ARF. INSTALLED ON Tl IE
STORi\C,E TANKS.
REFINERY MACT REQUIRES
PONCA CITY OK 7/1/2002 TANKS VARIES CERTAIN CONTROi. DEVICES
REFI Nl·.RY WI IICI I ARE INSTALLED ON THE
STORACiE TANKS
1\TOFINA l'ORT TK-800 ITR 1\RTIII IR TX 'i/I R/2/irl I NONE INDICATEll 4 05 LB/H
C ·oMPI .LX TANK
ATOFIN1\ PORT TK-80I FFR Alff lll lR TX 5/18/200 I NONE INDICATFll 4 Ir, l,B/H
COMPLl:X TANK
ATOFINA PORT TK-802 FFR ARTIII IR TX 5/1 8/200 I NONE INDI CATW 4 16 Ln/H
COMl'IXX TANK
ATOFIN!\ PORT TK-xn, IT R ARTIII IR TX ,1I xmInI NONI: INDICATED 2n Ul/I1
COMl'I.FX TANK
.'\TOFINA l'Oln TK-X077 IFR 1\J{ll II IR TX 5/1 8/211/l l NONI·: INDICAl'Ul I 2(, I.Bill
COMl'l.l:X TANK
llt\ VTO\\'N TX .1/5/20/l I T1\NK /.TK-llX Fl .O!\TIN<i ROOF OR 22 LB/H ()I l'.FINS l'I .ANT H)I IIVAI.FNT
BACY Analysis
,.
POLLUTANT COMPLIANCE NOTES
15
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
FACILITY PERMIT THRIJ THRU EMIS EMIS
FACILITY NAME PROCESS NAME PUT CONTROL DESCRIPTION LIMIT LIMIT I STATE DATE PUT UNIT 1 UNIT
Ill\ YTO\l'N TX -1/5/2()01 (cl Ti\NKS 7.TK-Fl.0/\TING ROOF OR 0 -1 LH/11 01 I .FINS l'l.i\NT n<li\&I\ H,ll I1\1/\1.ENT
lli\ YTO\\'N TX -1/'-/2(1(11 Ti\NK /.TK-I0 Fl .0/\TIN( i ROOF OR 0 51 IJ\/11 01 !'.FINS 1'1/\NT l'CJI IJ\1/\IY.NT
Ill\ YTOWN ·Ix -1/'-/2001 Ti\NK /.TK-II Fl.01\TIN(i ROOF OR 0 28 LB/1-1 01.1:FINS l'Li\NT U)IJ1\1 /\LENT
Si\lNT-<oOB/\IN Fl 11'1. Fl J(iJTIVES
VETROTF.X TX I I /1 .l/cnnn & llIESFI. NONE INlllCi\TFll J or, LB/I-I
i\Ml'RIC/\ STORMiE Ti\NK
\/!\ I.FRO
Rl'FININCi INTERNAL FL01\TI NG ROOF. COMl'ANY-TX (,/1 I /2002 TANKS 60000 C,1\ I.ii I 40 13 LIVI!
CORl'I IS CIIRISTI MONTI 11.Y !:MISSIONS Rl-:COR[)
RITINLRY
VAl.1'IW
RITININ<i INTERN1\L FI.OATJN(i ROOF. COMPANY-I X (,/1 I /2002 J'i\NKS (,OOilO Cit\ 1./11 -1013 Lil/II
CORl'I IS Cl IRIS 11 MONTI II Y EMISSIONS RECORll
Rl'l·INLRY
MARA l'IION FIXFll ROOF IN l'ERNAL FL01\TIN<, ROOF.
Pl' l'HOl.I:1I1\1 CO I.A 12/27/20()(, STORMiF TANKS COMPLY WITI I 40 l'FR (,J
LI.C SI JflP/\RT CC
MARA 11 ION INTl:RNAL INTERNAL FI.OATINCi ROOFS,
Pl'THOl.1:1 IM CO Li\ 12/27/200(, Fl .OA TIN(i ROOF COMPLY WITI I 40 cm !,_1
I IC STOHM,F TANKS SI I111'/\RT CC
BACT Analvsis
POLLUTANT COMPLIANCE NOTES
FUGITIVE EMISSIONS ARF. AN
ESTIMATE ONLY
16
CHEVRON PIPE LINE CO.
HANNA STATION
Table A-1 (Continued)
Summary of VOC BACT Determinations (per EPA's RBLC) for Storage Tanks
BACT Analvsis
. THRO EMIS . EMIS ' \ "'. " } .
FACILITY NAME FA~ll~l:Y PER:".'fr PROCESS NAME l HRU PUT CONTROL DESCRIPTION LIMIT LIMIT I. .POLLlffANTCOMPLIANCE NOTES SfArE DAIE PUT UNIT · · t . UNIT · · . '< > ·' " ... ,. .. y. •. .,.
MARATIION FXTlcRN/\1. EXTFRN/\L FUl/\TIN(i ROOr:
PFTIHll .Fl l~I co I .J\ I 2/~7/2(1()1, Fl .0 1\TIN(i Rnor COM l'I .Y inn I .j() CTR ()J
1.1.C STORA<iF.T1\NKS Sl/fll'/\RT CC S
17
RBLCII)
I 1,.nm .1
MT-11011
OK-1111~1)
OK-rnlX'>
OK-ll11')2
TX-ll2.15
TX-112:17
TX-02(,9
·1 X-ll2(,<>
r:\-0.l 1 ~
rX-ll.11.'
TX-ll.l 15
CHEVRON PIPE LINE CO.
HANNA STATION
Table B-1
Summary of VOC BACT Determinations (per EPA 's RBLC) for Fugitives
THRU
FACILITY NAME 1-"ACILITY PERMIT PROCESS NAME THRU PUT CONTROL DESCRIPTION STATE DATE PUT UNIT
FXXONMOllll 0 11. II, X/1')/200.1 Fl l(;JTIVFS NONI' INIJIC/\TEIJ c·oRl'(ll{t\TION
MONT1\NJ\ Rl-.l'ININ<i MT l/2J/l <)9R l.l(_)l llll (;ASOI.INI' NONI' INDICJ\TJ;D COMPANY FIJ<ilTIVF.
Fl l<ilTIVF. RIT INl:RY MACT RE<)I IIR ES
l't \NC/\ CITY RIT INl'RY OK 7/11211(12 COMl'ON l'.NTS/1'.f.l l lll'MF.NT INSl'l'.CTION AND MAINTl·:N/\NCI: OF
l'lJMP Sl·:AI.S. VAi.YES. FLAN(;Es. /\ND Ll:i\KS PIPES.
·11'11'1·.IIWl.l'I IM INC. CRI lllF I INIT Fl J(;ITIVF. LEAK lll:TF.CTION /\ND REPAIR (OVA VA l.l'RO AIWMOR I: OK (,/<)/200.1
Rl'.l·INl:RY EMISSIONS & Ml'TI IOD 211
VAi.FRO M{llMORI' OK I /I .1/2110.l CRI JllE I /NIT Fl IG!TIVE LEAK Dl'TECTION /\ND REPAIR
RIT INLRY 1:~IISSIONS l'ROC;RAM
EM ISSIONS /\RE ESTIMATES. NOT
V /\I.FRO RFFININ<; M/\XIMllM ALLOWABLE RATES
COMl'/\NY-CORI'! IS TX 6/11/2(1()2 FIJ(;ITIYES SPECIAL CONDITIONS APPLY FOR
MAINTEN/\Nl'E AND COMPLIANCE or CIIRISTI RIT INl:RY EQUIPMENT RELATED TO FUGITIVE
EM ISSIONS OF voe. SEE PERMIT
PORT A RTIII IR TX <)/R/1 <J<JR Fl l(;iT!YES 28 LAFR MONITORIN(i AND
RIT !NlcRY Mi\lNTENANCF l'ROGR/\M
SWFI-.NY TANK FARM TX i /8/19% l'l JMI' PIT ARE/\ FlJ<,ITIVES CONTROLLED WIT! I THE 28YI-II' LEAK
Dl:Tl:CTION AND REl'AIR PROGRAM
PROCESS FIJGITIYE EMISSIONS ARE
SWl'ENY IANK l'/\RM TX .'IX/I ')% TANK A REA FIJ(i!TIVl:S CONTROi.LED WITI I Tl IE 28VI II' LEAK
llETFCT!ON /\Nil REl'i\lR PROGRAM.
l:XXON MOBIi IIRI II' OFF-SITE Fl l(,ITIYI-.S
Ill\ YTOWN RIT INl'R Y TX 7/12/l')()I) (COOi.iNC; TOWl'R. l'lJMI'. NONE INlllCATEll
VALi
EXX<lN MOBIi FLl:XICOKIN(, Fl l(il rl Yl:S I.DAR l'IW(;R/\M (SEF. SPECIAL
Ill\ YTOWN lfrF INl'.R Y ·1 X 7/12/1'1')') ( FXK. l'RACTIONATOR. I.T CONlllTION #1:1 IN PERMIT) LNDSl
EXXON MOil i i. TX 7/12/1<)()() l'll'E STILL 7 FIJC;ITIYl:S l.lli\R PROGRAM (SEE SPECIAL
11/\YTOWN RIT INl:RY CONDITION# I :I IN PERMIT)
BACY Analvsis
EMIS EMIS EMIS LIMITl
LIMIT LIMIT AVG TIME
I I CONDITION UNIT
3.76 TPY
10 MCi/L
REFINERY
Mi\CT
10000 PPM lea~ detection. s~c
not~s
sec note
1655 LB/H
2.44 LB/H
1.83 LB/I-I
0.91 LB/II
3 2 LB/I-I
20.4 LB/I-I
0.9 1 LB/H
18
RBLCID
TX-ll1J,
TX-Ill!,
rx.n.1I,
T\-ll.121l
TX-OJ20
TX-ll.120
TX-lll20
TX-0.120
TX-ll.122
TX-ll322
TX-033:i
TX-0340
TX-ll.1-lll
CHEVRON PIPE LI NE CO.
HANNA STATION
Table B-1 (Continued)
Summary of VOC BACT Determinations (per EPA 's RBLC) for Fugitives
THRU
FACILITY NAME FACILITY PERMlT PROCF:ss NAME THRll PllT CONTROL DESCRIPTION STATE DATE PUT UNIT
l·.XXON MOIIII. ·1 X 7/J 2/1 C)()<) Rl :SIIJFINJN(i & 1'11'1: STILi, l,lli\R l'RO<iRi\M (SIT Sl'ECI/\L
Ill\ YTOWN RITINl·.RY X Fl l<illl \/I·.S CONIJITION 11I.li
I XXflN ~'iOIIII. TX 7/1 2/ I <Jtl<J SCI I 2 Fll(ilTIVF.S l.ll1\R J>R()(iRi\M (Sl'.F. Sl'ECI/\L
lli\YTOWN RITINFRY CONDITION# 13 OF PERMIT)
l'.XXON ~101lll TX 7/1 2/1 ')()() SOI IR Wi\Tl'R STRll'l'IN< i l.l)i\R PRO(,Ri\M (SFF SPECI/\L
Ill\ YTOWN Rl'.l·INl·.R Y f'I l(ilTIVES CONDITION# 13 OF PERMIT)
/\I.ON I IS/\ lllfi Sl'RINfi TX <J/2/I C)()') CRI 11)1' COMl'l.l:X 28\/1 II' Ll)i\R IUTINERY FIJ<,ITl\/I·:S. 02C RI ll>ITI I<,
/\I.ON I/Si\ lll(i Sl'RJN(i TX <J/2/f l)l)l) Fl JFI. GAS TRF/\TFR 2RVIII' I.DAR RFFINU{Y FI /CiJTIVIS IOHiTFllfi
/\I.ON I IS/\ Bl(i Sl'RIN(i TX 'l/2/I ()<)() I I )I I Fl /( ilTIVF.S. 28\/111' I.Di\R RITINl:RY O'lLDI JFI l(i
/\I.ON I IS/\ lll<i Sl'RINC. TX ')/2/1 ')')') PD/\ Fl IGJTI YES. 28\/1 IP LD/\R RFFINl'RY O'll'IMFl /(i
/\I.ON I IS1\ Jll(i Sl'RIN(i RFFORM/\TJ: SPI .ITTJ:R/CR
TX ()/2/1 <)')') COLI IMN Fl ICilTIVES. 2XV I II' Llli\R Rl:FINl'.RY 2f,MTFFlKi
CIHiO CORl'I JS Cl IRISTI PIWCTSS Fl JC,ITIVFS.5I7-RITINl:RY-WIS I TX 10/ I 5/1 'J'J'l NONE INDIC/\TEO
l'Li\NT S I-I
CIT<iO CORI'! IS Cl IRISTI SRlJ PROCESS FIJ(ilTJVES. REFINERY-WEST TX I 0/15/1909 553-FlJG NONE INDIC/\TED
l'l.i\NT
TRJ(iEi\NT COR Pl JS TX 8/7/2000 flJGITIVES. FUGITIVES NONE JNJ)JC/\TED CIIRISTI
1-:xxoN MORII. TX 4/1 J/200 I PROCESS r-tJGITIVES. I.SM, 28\/1·11' LDAR PROGRAM Bi\ YTOWN REFINl:RY l,SMFU<,
l'XXON ~Willi . TX -l/1 J/2110 I STOR/\C,E Ti\NK ll806. INTERN/\ I. FI.OATJN<, ROOF Ill\ YTOWN RIT INFRY TJ.;ORll(,
J
BACT Analvsis
EMIS EMIS EMTS LIMITt
LIMIT LIMIT AVG TIME
I I CONDITION UNIT
.142 LB/JI
42 LB/H
0.5 LB/II
8 03 LB/H
0 98 J,B/H
0 5 I LB/H
3 LB/H
0 55 LB/H
18.59 LB/H
I 05 LB/I-I
2. 19 LB/I-I
12 LB/H
0.16 LB/I-I
19
RBLCID
TX-ll.1-lR
TX-0.1-lR
TX-034~
TX-0348
TX-<l.1-JX
·1 X-OJ7r,
TX-ll.17r,
IX-037(,
TX-037/,
TX-0379
T\:-11.179
rX-04 I<,
I .. ·\-fl" I I
CHEVRON PIPE LINE CO.
HANNA STATION
Table 8-1 (Continued)
Summary of VOC BACT Determinations (per EPA 's RBLC) for Fugitives
THRU
FACILITY NAME FACILITY PERMIT PROCESS NAME THRU PUT CONTROL DESCRIPTION STATE DATE PUT liNIT
DIAMONll SIIAM IWCK TX Ill/I <)/2<Hll FI JC ilTIVES -NONF INlllCATF.ll MCKl:I·: l'LIINT ISOMFRIZATION. F-91
DIAMONll SIIA MROC:K TX 10/19/20()( Fl l(ilTIVES -NO .1 NONI-: INDICATEll MCKIT l'I /\NT RITORMFR
lllAMONll SI IAMROCK TX I 0/19/200 1 Fl/CilTIVl'S -NO. 3 SRl l. F-NONE INrnCATED MCKff PLANT 90
lllAMONll SI IAMIWCK TX 10/19/2001 FlJCilTIVES -NO 4 NONE INll!CATED MCKIT. Pl.i\NT I IYDROTRF.A TER. F-RR
lllAMONll SI IAMROCK TX f ()/f'l/20()( FllCilTIVF.S-Sl'I.ITTER. F-R'l NONE INDICATED MCKI-T. l'I ,\NT
llOW Tl'XAS TX 11/26/2002 PIPIN(i Fl l(ilTIVFS. NONE INDICATED Ol'l'RATIONS FR El:l'<lRT PRC )JECT A. AiOFI 10 I
llOWTl'XAS TX I I /26/2(1112 l'll'IN<. FlJ(ifTIVF.S. NONE INDI CATUJ OPERA llO NS FR IT l'ORT l'RO.IFCT fl. B7.Wl JOI
l)OWTI.X.'\S Tl lfUllNE I.I IBRICATION
Ol'l'RATIONS FRITl'ORT TX I I /2(,/2002 FlJ<rlTIVIS l'IW.11:CT A. NONE INDICATED
A50VI
llOW TEXAS Tl IRBINE Ll IRRICA TION
Ol'F.RATIONS FREEPORT TX 11/26/2()()2 FlJ<rlTIVES. l'IW.IECT B. NONE INl)(CATED
B73V4
l:XXONMOllll. FOLi.OW l'ROCEll lJRl'S FOR LEAK
lll:Al IMONT RIT INl:RY TX (,/10/2002 FCC! J Fl IGITIVl:S PREVENTION. DETECTION. AND
REPAIR
1:XXC>NMOllll. FCC! I FlJCilTIVl·.S FOi.i.OW l'ROCFlll lRES FOR LEAK
111·:AI IMONT Rl:FINl:R Y TX r,/J0/2<l02 (PRESCR l lllllER ). or,FG-00 1 l'Rl'.VENTION. llFTFCTION. AND
REPAIR
SI 11:1.1. 011. IJl :ER 1'1\RK T\: I I /24/1 <><)<J Fl ICilTIVE. Pll'IN<, I.EAK DETl:CTION AN() REPAIR
l'Rll<,RAM
~1ARATI ION I.A I 2/ 2 7 /201l(, Fl l(;JTIVI: 1:MISSIONS I.A lffFINl·.RY MACT l'l'.TROl.l.-1 IM en I I.C
BACT Analvsis
E1'-US EM.IS EMISLIMIT I
LIMlT Lll\,UT AVG TIME
1 I CONDITION UNIT
1.46 LB/H
1.04 LB/H
0.21 LB/H
1.2 LB/H
0.23 LB/H
0.136 LB/H
0.136 LB/H
0.006 LB/I-I
0.006 LB/H
9 84 LB/H
9.85 LB/I-I
0 09 I.BIi i
20
(1/.29/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments ..
From:
To:
CC:
Date:
Subject:
Hi Tim,
<[e-mail]>
"Tim Dejulis" <[e-mail]>
<Jim [e-mail]>
1/28/2009 6:57 PM
Re: CPL Hanna Station Plan Review comments
We would like the permit to go to public comment as soon as possible, but
would like to review a draft first. Below are response to your questions
and some issues that we need clarifications on.
TD,UDAQ: AH7: Monitoring of opacity is a condition that appears in every
permit that DAO issues. 10% is based on the fuels being consumed or
processed in the plant. This condition must remain.
AH, URS: We continue to be concerned about the inclusion of this clause.
The Hanna Station is located in an attainment area. Normal operation of
this station is not expected to impact opacity because there are no
particulate matter (PM) sources in this facility: equipment being permitted
does not consume fossil fuel or emit PM; comfort heaters consuming propane
are exempt from this permit; pumps using electricity are not emission
sources. The facility emits only VOCs which originate from storage tanks
and pipeline components, not from combustion sources. Please reconsider
this condition for this facility which does not have a source that would
impact opacity.
If you determine that opacity observation is still required, please propose
language that clarify when and who will conduct the observation. For this
case, our preference would be for UDAQ to conduct opacity observation as
needed. If this is unacceptable, we would like to conduct the observation
only when requested by UDAQ.
TD,UDAQ: Thank you for your suggested condition language. Throughput is
usually monitored on a daily basis and tallied (record keeping) by the 20th
of each month. Reporting is on demand. Is there a truly compelling reason
for the suggested monitoring, record keeping, and reporting schedule?
AH, URS: We have suggested the record keeping and reporting schedule
because throughput records may not be readily available by the 20th of each
month. The facility is an unmanned breakout station, although employees
make routine visits. In addition, crude handled at the facility is not
sold. At the Hanna Station, there are meters on the incoming and outgoing
lines that provide the data to determine throughput.
Suggested new text: To determine compliance with a rolling 12-month total,
the owner/operator shall calculate a new 12-month total by the twentieth
day of each month using data from the previous 12 months. Records shall be
made available to the Executive Secretary or Executive Secretary's
representative upon request.
Record keeping for two years was added for clarification. The two-year
record keeping schedule reiterates the requirement already set forth under
Section I, General Provisions. The original text of this condition can be
confused to mean throughput records shall be kept for the life of the
facility.
TD, UDAQ: Natural gas fuel combustion has different emissions than propane
although these two emissions profiles are similar. It is unusual to be able
to use propane and natural gas flexibly in comfort heating devices without
a mechanical conversion. Also, natural gas is generally a cheaper commodity
than propane so a source will use propane as a back-up if natural gas is
unavailable. Do you mind offering a explanation/clarification in this
matter?
AH, URS: Equipment using either propane or natural gas with rated capacity
less than 5 million BTU per hour is category exempt under R307-401-1 o.
Page 1
(1/~9/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments
Since these comfort heaters are exempt, can condition I1.B.1.d be removed
from the permit? The comfort heaters currently run on propane, but we would
like flexibility to use natural gas for heating if that becomes available
in the future.
Regards,
Autumn
Autumn Hu
Environmental Engineer
URS Corporation
756 E Winchester St, Suite 400, Salt Lake City, UT 84107
TEL: [phone] FAX: [phone]
Email: [e-mail]
This e-mail and any attachments are confidential. If you receive this
message in error or are not the intended recipient, you should not retain,
distribute, disclose or use any of this information and you should destroy
the e-mail and any attachments or copies.
"Tim Dejulis"
<[e-mail]>
01/22/2009 04:51 PM
To
<[e-mail]>
cc
Hi Autumn,
Subject
Re: CPL Hanna Station Plan
Review comments
Responses to the points you raise are as follows:
AH1: NAO 1983 appears in the database. Why it does not appear in the
document created by the database is not known to me but it will be correct
before the public comment starts.
AH2: I see that your calculations list 12.27 tons. The forms you offered _
list 12(.00) so it was a routine matter for me to use the lower number.
12.27 tons will appear in the intent to approve document.
AH3: These are some of those wildcard characters I warned you about.
Please pay no attention to them.
AH4: 12.21 tpy voe.
AH5: As far as biphenyl, cresol, and cumene are concerned these emission
rates are less than 10 pounds per year each and so not listed. Total HAPs
are 0.33 tpy.
AH6: We discussed this. The condition references compliance with R307-150.
Page 2
(1/29/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments
If this rule doesn't apply then there's no exposure. All things being
equal the DAO will leave this condition in the permit.
AH7: Monitoring of opacity is a condition that appears in every permit
that DAO issues. 10% is based on the fuels being consumed or processed in
the plant. This condition must remain .
Thank you for your suggested condition language. Throughput is usually
monitored on a daily basis and tallied (record keeping) by the 20th of each
month. Reporting is on demand. Is there a truly compelling reason for the
suggested monitoring, record keeping, and reporting schedule?
Natural gas fuel combustion has different emissions than propane although
these two emissions profiles are similar. It is unusual to be able to use
propane and natural gas flexibly in comfort heating devices without a
mechanical conversion. Also, natural gas is generally a cheaper commodity
than propane so a source will use propane as a back-up if natural gas is
unavailable. Do you mind offering a explanation/clarification in this
matter?
Considering that several important structural changes will be made prior to
start of the public comment period would there be any objection to starting
the public comment period in the next ten days?
Regards,
Timothy DeJulis
>» <Autumn_Hu @URSCorp.com> 1/15/2009 9:57 AM >>>
Hi Tim,
Attached are my comments for the Chevron Pipe Line Hanna Station Plan
Review. I have used "track changes" in MS Word. Also, I have attached is
PDF version in case the Word version does not work for you. Please let me
know if you have any questions.
Regards,
Autumn.
(See attached file: Chevron Pipeline 10213 -2008 (CPL).rtf) (See
attached file: Chevron Pipeline 10213 -2008 (CPL).pdf)
Autumn Hu
Environmental Engineer
URS Corporation
756 E Winchester St, Suite 400, Salt Lake City, UT 84107
TEL: [phone] FAX: [phone]
Email: [e-mail]
This e-mail and any attachments are confidential. If you receive this
message in error or are not the intended recipient, you should not retain,
distribute, disclose or use any of this information and you should destroy
the e-mail and any attachments or copies.
Page 3
(?/11/2009) Tim Dejulis -~e: CPL Hanna Station Plan Review comments
From:
To:
Date:
Subject:
Hi Tim,
<[e-mail]>
"Tim Dejulis" <[e-mail]>
2/11/2009 3:37 PM
Re: CPL Hanna Station Plan Review comments
Based on our conversion on Monday (2/9/2009), please considered the text
revisions below.
Inventory: Provision 1.6
· The owner/operator shall comply with R307-150 Series. Inventories, Testing
and Monitoring. [R307-150]
--->Chevron understands that this provision will be retained.
Opacity: Provision 11.B.1.a
Visible emissions from any stationary point or fugitive emission source
associated with the source or with the control facilities shall not exceed
10% 20% opacity. Opacity observations of emissions from stationary sources
shall be conducted at an acceptable frequency, in accordance with 40 CFR
60, Appendix A, Method 9. [R307-401]
---> Based on your previous email response, Chevron understands that a 20%
opacity limit will be used. ·
Rolling 12-month totals: Provision 11.B.1 .b
To determine compliance with a rolling 12-month total, the owner/operator
shall calculate a new 12-month total by the twentieth day of each month
using data from the previous 12 months. Records of crude oil throughput
shall be kept for all periods when the plant is in operation. Crude oil
throughput shall be determined by examination of company and/or customer
billing records. The records of crude oil throughput shall be kept on a
daily basis .. [R307-401]
--->Chevron is prepared to calculate a rolling 12-month throughput total by
the 20th of each month. However, we feel that daily record of throughput
is unnecessary. At the Hanna Station, there are meters on the incoming and
outgoing lines that provide the data to determine monthly throughput. The
facility is an unmanned breakout station. A minimum monthly visit would
provide the required data; a daily record of throughput wou ld result in
unnecessary visits .to this facility.
Fuel for heaters: Provision I1.B.1.d
The owner/operator shall use propane as fuel in th e various compfort
comfort heating devices. [R307-401]
--->Chevron understands that this provision will be retained.
Regards,
Autumn
Autumn Hu
Environmental Engineer
URS Corporation
756 E Winchester St, Suite 400, Salt Lake City, UT 84107
TEL: [phone] FAX: [phone]
Email: [e-mail]
This e-mail and any attachments are confidential. If you receive this
message in error or are not the intended recipient, you should not retain,
distribute, disclose or use any of this information and you should destroy
the e-mail and any attachments or copies.
Page 1
(2/?-1/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments
"Tim Dejulis"
<[e-mail]>
02/04/2009 02:49 PM
To
<[e-mail]>
cc
Hi Autumn,
Subject
Re: CPL Hanna Station Plan
Review comments
With respect to opacity: compliance with opacity is a continuous obligation
on the part of the source. Rule 307-205 applies to sources in attainment
areas regardless of whether or not a reference to this rule appears in a
permit. This rule specifies a 20% opacity limit. It is Chevron's
obligation to demonstrate compliance with this rule. I would refer you to
compliance personnel with regards to their policy in these matters.
However, 10% opacity is routinely specified for combustion units using
natural gas or propane and it is unlikely that the Hanna Pipeline will ever
violate 10% opacity, so this is a reasonable limit. In the interest of
moving forward it will be possible to identify 20% vs 10%.
On exempted equipment items: many times DAO is placed in the position of
evaluating emissions from equipment identified for exemption from Notice of
Intent and permit requirements under R307-401-10. As you read this rule
citation you'll notice that the type of fuel employed effects the exempt
status capacity limits of the unit. It will be possible to identify these
units as, "For informational purposes only," but experience in these
matters dictates some reference to their existence in the permit.
As to fuel requirements: we require fuels to be specified in a permit
regardless of the applicability of R307-401-10. The emission profiles for
various fuels are different -there are differences between natural gas and
propane owing to each fuel's energy value. Propane's fuel value is
specified in terms of Btu per gallon compared to natural gas in terms of
Btu per cubic foot. The NOi specifies two propane space heaters. No
emissions estimates.were produced using either propane or natural gas as
the primary fuel. You can take the fact that I have not asked you for them
to mean that DAO understands that the potential NOx and CO from these space
heaters is likely to be less than eight ounces per day. Technically your
NOi is incomplete, however.
On rolling 12-month totals: Chevron has from the 21st of one month until
the 20th of the following month to update the rolling 12-month total for
the Hanna station. Chevron is certainly in the business of tracking every
gallon of material that flows-through their pipelines on an ongoing basis.
Chevron can keep the records as long as they like, but we use the permit
language that you refer to be consistent for all sources in this regard,
unless a truly compelling reason for an alternate can be offered in
writing. Different people can interpret a condition in different ways, but
to be candid this is the first time anyone suggested an interpretation
requiring that records be maintained for all time. It might interest you
to know that DAO policy is to avoid specifying the same thing more than
once in a permit. For example, if I were to do as you suggest and list the
Page 2
(2J;i 1/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments
times frame in two places, does Chevron get two violations for not
preserving records?
This is a really simple operation and a simple permit. Compliance at this
plant should be a walk in the park compared to other operations. Why don't
we move forward now?
Regards,
Timothy DeJulis
>>> <Autumn_Hu @URSCorp.com> 1/28/2009 6:57 PM >>>
Hi Tim,
We would like the permit to go to public comment as soon as possible, but
would like to review a draft first. Below are response to your questions
and some issues that we need clarifications on.
TD,UDAQ: AH?: Monitoring of opacity is a condition that appears in every
permit that DAO issues. 10% is based on the fuels being consumed or
processed in the plant. This condition must remain.
AH , URS: We continue to be concerned about the inclusion of this clause.
The Hanna Station is located in an attainment area. Normal operation of
this station is not expected to impact opacity because there are no
particulate matter (PM) sources in this facility: equipment being permitted
does not consume fossil fuel or emit PM; comfort heaters consuming propane
are exempt from this permit; pumps using electricity are not emission
sources. The facility emits only VOCs which originate from storage tanks
and pipeline components , not from combustion sources. Please reconsider
this condition for this facility which does not have a source that would
impact opacity.
If you determine that opacity observation is still required, please propose
language that clarify when and who will conduct the observation. For this
case, our preference would be for UDAQ to conduct opacity observation as
needed. If this is unacceptable, we would like to conduct the observation
only when requested by UDAQ.
TD,UDAQ: Thank you for your suggested condition language. Throughput is
usually monitored on a daily basis and tallied (record keeping) by the 20th
of each month. Reporting is on demand. Is there a truly compelling reason
for the suggested monitoring, record keeping, and reporting schedule?
AH, URS: We have suggested the record keeping and reporting schedule
because throughput records may not be readily available by the 20th of each
month. The facility is an unmanned breakout station, although employees
make routine visits. In addition, crude handled at the facility is not
sold. At the Hanna Station, there are meters on the incoming and outgoing
lines that provide the data to determine throughput.
Suggested new text: To determine compliance with a rolling 12-month total,
th e owner/operator shall calculate a new 12-month total by the twentieth
day of each month using data from the previous 12 months. Records shall be
made available to the Executive Secretary or Executive Secretary's
representative upon request.
Record keeping for two years was added for clarification. The two-year
record keeping schedule reiterates the requirement already set forth under
Section I, General Provisions. The original text of this condition can be
confused to mean throughput records shall be kept for the life of the
facility.
TD, UDAQ: Natural gas fuel combustion has different emissions than propane
although these two emissions profiles are similar. It is unusual to be able
to use propane and natural gas flexibly in comfort heating devices without
Page 3
(2/t1/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments ·
a mechanical conversion. Also, natural gas is generally a cheaper commodity
than propane so a source will use propane as a back-up if natural gas is
unavailable. Do you mind offering a explanation/clarification in this
matter?
AH , URS: Equipment using either propane or natural gas with rated capacity
less than 5 million BTU per hour is category exempt under R307-401-10.
Since these comfort heaters are exempt, can condition I1.B.1.d be removed
from the permit? The comfort heaters currently run on propane, but we would
like flexibility to use natural gas for heating if that becomes available
in the future. ·
Regards,
Autumn
Autumn Hu
Environmental Engineer
URS Corporation
756 E Winchester St, Suite 400, Salt Lake City, UT 84107
TEL: [phone] FAX: [phone]
Email: Autumn_Hu @URSCorp.com
This e-mail and any attachments are confidential. If you receive this
message in error or are not the intended recipient, you should not retain,
distribute, disclose or use any of this information and you should destroy
the e-mail and any attachments or copies.
"Tim Dejulis"
<tdejulis @utah.gov>
01/22/2009 04:51 PM
To
<Autumn_Hu @URSCorp.com>
cc
Hi Autumn,
Subject
Re: CPL Hanna Station Plan
Review comments
Responses to the points you raise are as follows:
AH1 : NAO 1983 appears in the database. Why it does not appear in the
document created by the database is not known to me but it will be correct
before the public comment starts.
AH2: I see that your calculations list 12.27 tons. The forms you offered
list 12(.00) so it was a routine matter for me to use the lower number.
12.27 tons will appear in the intent to approve document.
AH3: These are some of those wildcard characters I warned you about.
Please pay no attention to them.
Page 4
(?/11/2009) Tim Dejulis -Re: CPL Hanna Station Plan Review comments
AH4: 12.27 tpy voe.
AH5: As far as biphenyl, cresol. and cumene are concerned these emission
rates are less than 10 pounds per year each and so not listed. Total HAPs
are 0.33 tpy.
AH6: We discussed this. The condition references compliance with R307-150.
If this rule doesn't apply then there's no exposure. All things being
equal the DAO will leave this condition in the permit.
AH7: Monitoring of opacity is a condition that appears in every permit
that DAO issues. 10% is based on the fuels being consumed or processed in
the plant. This condition must remain.
Thank you for your suggested condition language. Throughput is usually
monitored on a daily basis and tallied (record keeping) by the 20th of each
month. Reporting is on demand. Is there a truly compelling reason for the
suggested monitoring, record keeping, and reporting schedule?
Natural gas fuel combustion has different emissions than propane although
these two emissions profiles are similar. It is unusual to be able to use
propane and natural gas flexibly in comfort heating devices without a
mechanical conversion. Also, natural gas is generally a cheaper commodity
than propane so a source will use propane as a back-up if natural gas is
unavailable. Do you mind offering a explanation/clarification in this
matter?
Considering that several important structural changes will be made prior to
start of the public comment period would there be any objection to starting
the public comment period in the next ten days?
Regards,
Timothy DeJulis
>>> <[e-mail]> 1/15/2009 9:57 AM »>
Hi Tim,
Attached are my comments for the Chevron Pipe Line Hanna Station Plan
Review. I have used "track changes" in MS Word. Also, I have attached is
PDF version in case the Word version does not work for you. Please let me
know if you have any questions.
Regards,
Autumn.
(See attached file: Chevron Pipeline 10213 -2008 (CPL).rtf) (See
attached file: Chevron Pipeline 10213 -2008 (C PL}.pdf}
Autumn Hu
Environmental Engineer
URS Corporation
756 E Winchester St, Suite 400, Salt Lake City, UT 84107
TEL: [phone] FAX: [phone]
Email: Autumn_Hu @URSCorp.com
This e-mail and any attachments are confidential. If you receive this
message in error or are not the intended recipient, you should not retain,
distribute, disclose or use any of this information and you should destroy
the e-mail and any attachments or copies.
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