ISSUED BY THE DEPARTMENT OF ENVIRONMENTAL QUALITY

Issued Permit Number: 26-2029-TV-01Expiration Date: 04/01/2023

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OREGON DEPARTMENT OF ENVIRONMENTAL QUALITYOREGON TITLE V OPERATING PERMIT

DEQNorthwest Region

700 N.E. Multnomah St., Suite 600Portland, OR 97232

Telephone: (503) 229-5263

Issued in accordance with the provisions ofORS 468A.040,468A.300,and based on the land use compatibility findings included m the permit record.

ISSUED TO: INFORMATION RELIED UPON:

Shore Terminals LLC Application Number: 0303429420 NW St. Helens Road Received: 10/01/2018Portland, OR 97231

PLANT SITE LOCATION: LAND USE COMPATIBILITY STATEMENT:

9420 NW St. Helens Road Prom: City of PortlandPortland, OR 97231 Dated: 08/27/1991 & 01/25/1993

ISSUED BY THE DEPARTMENT OF ENVIRONMENTAL QUALITY

10-^-20'^^.O.'bSteven A. Dietrich, Northwest Region AQ Manager Date

Nature of Business: Special warehousing and storage facilities for hire / Bulk Gasoline Terminal

Primary SIC: 4226 Primary NAICS: 493190Secondary SIC: 5171 Secondary NAICS: 424710

RESPONSffiLE OFFICIAL:FACILITY CONTACT PERSON:

Title: Terminal Manager

Phone: 503-286-6732 Name: Chris ChanTitle: Sr. HSE Manager, West RegionPhone: (906)509-3279

Issued Permit Number: 26-2029-TV-01

Expiration Date: 04/01/2023 of 50

TABLE OF CONTENTS

LIST OF ABBREVIATIONS USED IN THIS PERMIT................................................................................................... 3

PERMITTED ACTIVITIES.

EMISSIONS UNIT (EU) AND POLLUTION CONTROL DEVICE (PCD) IDENTIFICATION.................................. 4

EMISSIONS UNIT (EU) AND POLLUTION CONTROL DEVICE (PCD) IDENTIFICATION.................................. 6

EMISSION LIMITS AND STANDARDS.

PLANT SITE EMISSION LIMITS.....................................................................................................................^^

TEST METHODS AND PROCEDURES ......................................................................................................................... 30

GENERAL MONITORING AND RECORDKEEPING REQUIREMENTS ................................................................. 31

REPORTING REQUIREI^NTS...............................................................................................................^^

NON-APPLICABLEREQmREMENTS.............................................................................................................^

GENERAL CONDITIONS.....................................................................................................................^

ATTACHMENT 1............................................................................................................................................

ATTACH]\ffiNT 2.......................................................................................................................................


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LIST OF ABBREVIATIONS USED IN THIS PERJMIT

ACDPacfm

ActAQMAASTMBtuCAMCFRGOC02C02eCOMSCPMSDEQdscfEFEPAEUFCAAFSAGHGgr/dscf

HAP

HCFCH2SIDI&MNAIDI&MLPGMBmg/1mvac

Air Contaminant Discharge Permitactual cubic foot per minute

Federal Clean Air ActAir quality management area

American Society of Testing and MaterialsBritish thermal unitCompliance Assurance MonitoringCode of Federal RegulationsCarbon MonoxideCarbon dioxide

carbon dioxide equivalentContinuous opacity monitormg systemContinuous parameter monitoring system

Department of Environmental QualityDry standard cubic feetEmission factorUS Environmental Protection AgencyEmissions UnitFederal Clean Air ActFuel sampling and analysisgreenhouse gas

Grain per dry standard cubic feet(1 pound =7000 grains)

Hazardous Air Pollutant as defined by OAR340-244-0040

HalogenatedChloro-Fluoro-Carbons

Hydrogen SulfideIdentification number or labelInspection and maintenance

Not applicableIdentification numberInspection and maintenanceLiquefied petroleum gasMaterial balancemilligrams per literMotor vehicle air conditioner

NGNOx02OARODEQ

ORSO&MPbPCDPMPMio

PM2.5

PSDPSELpsiaRACTscfSERSERPSIPSNAPS02STvcuVEVMTvocVOHAVRUWSPA

Natural gas

Nitrogen oxides

OxygenOregon Administrative RulesOregon Department ofEnvu-onmental

QualityOregon Revised StatutesOperation and maintenance

LeadPollution Control DeviceParticulate matterParticulate matter less than 10 microns in

size

Particulate matter less than 2.5 microns insize

Parts per millionPrevention of Significant Deterioration

Plant Site Emission Limitpounds per square inch, actualReasonably Available Control TechnologyStandard cubic footSignificant Emissions Rate

Source emissions reduction plan

State Implementation PlanSignificant New Alternative Policy

Sulfur dioxideSource test

Vapor Combustion UnitVisible emissionsVehicle miles traveledVolatile organic compounds

VOHAP Volatile organic hazardous air pollutantsVapor Recovery UnitWestern State Petroleum Association


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PERMITTED ACTIVITIES

1. Until such time as this permit expu-es or is modified or revoked, the permittee is allowed to discharge aircontaminants from those processes and activities directly related to or associated with air contaminantsource(s) in accordance with the requirements, limitations, and conditions of this permit. [OAR 340-218-0010 and 340-218-0120(2)]

2. All conditions in this permit are federally enforceable, meaning that they are enforceable by DEQ,EPA,and citizens under the Clean Au- Act, except Conditions 13, 14, 15, 05, and G9 (OAR 340-248-0005through 340-248-0180) are only enforceable by the state. [OAR 340-218-0060]

EMISSIONS UNIT fEU) AND POLLUTION CONTROL DEVICE OPCD) IDENTIFICATION

3. The emissions units and pollution control devices regulated by this permit are the following [OAR 340-218-0040(3)]:

3 .a. Fixed Roof Tanks (FIXTANK) regulated by this permit are the following:

FIXTANK Description

A fixed roof storagetank dedicated to storepetroleum distillates

FIXTANK DeviceID Number

2511251259192705

Rated Capacity (gallons)

971,474971,474

2,230,8231,134,000

Year Installed

1925192419351976

3 .b. Internal Floating Roof Tanks (INTANK) regulated by this permit are the followmg:

INTANK Description

All Internal floating roofstorage tanks at thefacility.

INTANK DeviceID Number

59015902703800680078308520935102113361456182020202120221009101010112706320132033204440245076408


2,222,3722,222,372279,576

3,045,4923,045,4923,147,8011,970,0521,312,455772,794

1,343,4002,099,063770,891770,891770,891420,000420,000420,000

1,134,0001,344,0001,344,0001,344,0001,848,0001,890,0002,688,000

Year Installed

192919291938195319531969197119371938195819581935193519351976197619761976197619761976197619761976


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INTANK - Continued

INTANK Description

WTANKKB subject toNSPSsubpartKb-equivalent Requirements

INTANK DeviceID Number

10026100273605


5,040,0005,040,0001,346,324

Year InstalledOr modified

200720072019

3.c. Marine Loading Operations (MLOAD) regulated by this permit are the following:

Marine Loading OperationsDescription

Marine tanker ship and barge loadmgoperations conducted at the terminaldocks, when loading gasoline andvolatile liquid products.

MLOADDevice ID

MLOAD2MLOAD3

Pollution ControlDevice (PCD)

Vapor CombustionUnit

PCDID

vcu

3 .d. Tanker Truck/Trailer Loading Racks (TRACK) regulated by this permit are the following:

TRACK DescriptionTanker truck and trailerloading operations conductedat the terminal

Pollution Control Device (PCD)

Vapor Combustion Unit (VCU)

Vapor Recovery Unit used as a back-up to VCUduring maintenance and/or breakdown ofVCU

3.e. The piping components (PIPES) regulated by this permit are the following:

PIPES Description

VOC emissions from Flanges, valves,pumps, etc. at Terminal

PIPES Device ID

PIPES

3.f. Fuel Combustion sources (BOILER) regulated by this permit are the following:

BOILER Description

The boiler's rated capacity is 15x106 Btu/hr,capable of burning NG, LPG, & low-sulfur diesel.

BOILER Device ID

BOILER

4. The permittee is allowed to convert or modify any FIXTANK or INTANK identified in Conditions 3.a and3.b, or add new VOC abatement devices identified in Conditions 3.c and 3.d, provided the applicablerequirements are strictly adhere to. [OAR 340-218-01 40]

EU IDAny FIXTANK identified inCondition 3.a.

Any INTANK identified inCondition 3.b.

VCU identified in Conditions3.c and 3.d

Description of ModiHcation/Construction

Fixed Roof Storage tank retrofitted with an internal floatingroof, a device whose primary function is reduction of airpollutant (e.g., VOC).

Internal Floating Roof Storage tank retrofitted with better roofseals or rebuilt with a domed internal floating roof withoutincreasing the storage capacity.

Vapor Combustion Unit to abate VOC emissions fromMLOAD and TRACK operations


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4.a. The permittee must complete and submit a Notice of Approval Form (MD901) prior toconstruction or modification described above, except for VCU.

4.b. Unless otherwise notified by DEQ, the permittee may proceed with the construction ormodification 10 days after DEQ receives the NOA form (MD901) required m Condition 4.a.

4.c. The permittee must notify DEQ within 30 days of completion of modification or construction ofeach device. The Notice of completion form submitted pursuant to OAR 340-210-0240(3) shallinclude the date of completion of modification or construction, and the date the device was or willbe put into operation.

5. Internal Floating Roof Tanks (INTANKm) that are currently or will become subject to the NSPS subpartKb-equivalent requirements specified in Conditions 29, 30, 31, and 32 are the following:

INTANKKBDescription

Any FIXTANK or INTANK that willbe retrofitted and/or converted to aninternal floating roof tank perCondition 4.

INTANKKBDevice ID

10026100273605

Rated Capacity(gallons)5,040,0005,040,0001,346,324

Yr. Installed/Modified

200720072019

future project

ALTERNATIVE OPERATION SCENAMOS

6. The permittee must operate the Vapor Combustion Unit (VCU) and the backup Vapor Recovery Unit(VRU) under the following operating scenarios: [OAR 340-218-0140(1)]

6.a. In the Normal Operating Scenario (OS #1), Vapor Combustion Unit (VCU) identified inConditions 3.c and 3.d is used to abate VOC emissions from marine loading (MLOAD) and/ortruck/trailer loading (TRACK) operations.

6.b. In the Alternative Operating Scenario 2 (OS #2), the backup VRU identified in Condition 3 .d isused to abate VOC emissions from Tanker truck/trailer loading racks (TRACK) operations.

6.c. The permittee must contemporaneously record changes from one alternative operatmg scenario to

another. The record must be made available or submitted upon request by DEQ. [OAR 340-218-0140(l)(c)]


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EMISSION LIMITS AND STANDARDS

Table-I through Table-III contain summaries of applicable requirements other than the Plant Site Emission Limits(PSEL), along with testing, monitoring, and recordkeeping requirements for the emissions units to which thoserequirements apply.

Table-I. Facility-wide Emission Limits and Standards

Applicable RequirementsOAR / 40 CFR

340-228-0100

340-228-0110

340-258-0400

340-206-0050

340-208-0300

40 CFR Part 68

340-214-0110

Cond No.

7

7

9

11

13

16

15

Pollutant/

Parameter

Residual oilsulfur content

Distillate fueloil S content

voc

Ozone

Nuisance

RiskManagement

voc

Limit/Standard

1.75% by weight

0.3% by weight0.5% by weight

RVP Standards

SERP

no nuisance

Monitoring RequirementsMethod

%Sulfur Analysis& Recordkeeping

%Sulfur Analysis& Recordkeeping

Testing andRecordkeeping

Recordkeeping

ComplaintInvestigation &

Recordkeeping

Risk management plan

Notification Required

Cond No.

8

8

10

12

14

16

15

7. FUEL SULFUR CONTENT The permittee must not sell, distribute, use, or make available for use thefollowing fuel oils:

7.a. Any residual fuel oil containmg more than 1.75 percent sulfur by weight; [OAR 340-228-0100]7.b. ASTM Grade-1 distillate fuel oil containing more than 0.3 percent sulfur by weight; and7.c. ASTM Grade-2 distillate fuel oil containing more than 0.5 percent sulfur by weight. [OAR 340-

228-0110]7.d. Exemption: Fuels used exclusively for the propulsion and auxiliary power requirements of

vessels, raikoad locomotives, and diesel motor vehicles are not subject to the sulfur limitsspecified in this condition.

8. MONITOR AND RECORD The permittee must monitor the sulfur content of each batch of residual oil andASTM grade distillate oil sold, distributed, or used, in accordance with one of the following methods orprocedures:

8.a. Analyze or have analyzed by a contract laboratory a composite of representative samples taken by

the permittee from each new batch of fuel oil received. Liquid fuels must be analyzed usingASTM D129-64, Dl 552-83, or D4057-81 Method;

8.b. obtain a sulfur analysis certificate from the vendor for each new batch of fuel oil received; or8.c. for fael oil received via the (Olympic) pipeline, the permittee must retain contractual agreements

providing that the sulfar contents of residual or distillate fuel oils entering the pipeline from therefinery are within the limits specified in this permit.



9. RVP STANDARD During the regulatory control period of May 1 through September 15 of any calendaryear, the permittee must comply with the applicable RVP standards of gasoline and gasohol distributed mthe control area and other associated requirements of 40 CFR 80, as referenced in OAR 340-258-0400:

9.a. The geographic coverage (i.e., control area) shall be consistent with boundary specified in ASTMD439 of 40 CFR 80, specifically all of Oregon, west of 122 degrees Longitude.

9.b. The RVP standard of gasoline distributed in the month of May must be less than 9.0, and the RVPstandard of gasoline distributed in the subsequent control period must be less than 7.8.

9.c. The RVP standards ofgasohol that meets the requirements of 40 CFR 80.27(d)(2) are 1 pound persquare inch (1.0 psi) greater than the gasoline RVP standards specified in item 9.b.

10. MONITOR AND RECORD The permittee must mamtain records of the RVP values (psi) of all gasolinedistributed during the control period. RVP values must be measured according to the proceduresestablished in the most current method ofASTM D323 or established based on batch certifications fromsuppliers. The permittee must summarize the amount and RVP values (psi) ofgasoline/gasohol distributedon a monthly basis and submit the monthly RVP report to the Department by no later than the 15th day afterthe end of each calendar month of the control period. [OAR 340-258-0400]. The report must summarizethe amount of gasoline and gasohol distributed in accordance with the following categories:

lO.a. Gasoline with RVP values < 7.8 psi

lO.b. Gasoline with RVP values > 7.8 psi < 9 psi10.c. Gasoline with RVP values > 9 psi

lO.d. Gasohol with RVP values < 8.8 psi;

10.e. Gasohol with the RVP values > 8.8 psi < 10 psi; and10.f. Gasohol with RVP values > 10 psi.

11. SOURCE EMISSION REDUCTION PLAN In the event an An- Pollution Alert, Warning, or EmergencyEpisode for ozone is declared in the Portland area by the Department, the permittee must take the actionappropriate to the episode condition as described below. The permittee must take such action when thepermittee first becomes aware of such a declaration whether through news media, direct contact with theDepartment, or from other sources. [OAR 340-206-0050]

11 .a. ALERT: Notify the employees and prepare to take possible further action in case theepisode escalates into a warning or an emergency stage. Employees may

voluntarily reduce operations of personal motor vehicle.

11 .b. WARNING: Maintain required action of Alert conditions. Ensure proper operation of VaporRecovery Units during tank truck loading operations.

ll.c. EMERGENCY: Maintain required action of Warning condition. Cease all marine loadingoperations (MLOAD) of gasoline, unless control strategies are utilized to reduceVOC emissions from MLOAD by at least 95%.

12. MONITOR AND RECORD The permittee must maintain a log summarizing actions taken during anapplicable air pollution episode, pursuant to Condition 11,if any.

13. NUISANCE PROHIBITION The permittee must not cause or allow air contaminants from any source to

cause a nuisance. Nuisance conditions will be verified by Department personnel. [OAR 340-208-0300][State-only enforceable]

14. MONITOR AND RECORD The permittee must maintain a log of each nuisance complaint received by thepermittee during the operation of the facility. Documentation must include date of contact, time of


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observed nuisance condition, description of nuisance condition, location ofreceptor, status of plant

operation during the observed period, and time of response to complainant. A plant representative must

immediately investigate the condition following the receipt of the nuisance complaint and a plantrepresentative must provide a response to the complainant within 24 hours, if possible.

15. NOTIFICATION REQUIREMENT The permittee must notify the Department when it is necessary to drainand ventilate (i.e. degas) any storage tank that stores gasoline, ethanol, or diesel fuel as follows:

15 .a. Notice must be given:

15.a.i. at least 7 calendar days before degassing begins whenever possible; or15.a.ii. as soon as possible before degassing begins if the permittee has less than 7 days

advance notice themselves, such as when degassing for emergencies or sudden

product changes.

15.b. DEQ must be notified both by phone and by fax or email as follows:

15.b.i. By phone call 503-229-5263, and:

15.b.i.(l) If the office is open, ask for the Air Quality Duty Officer and provide notice tothe Duty Officer or leave a voice message with the information below;

15.b.i.(2) If the office is closed, leave a voice message with the information below.

15.b.ii. Send a fax addressed to "AQ Section" to 503-229-6945, or send an email to thepermit writer, with the information detailed in 15.c:

15 .c. Required information:

15.C.L Permittee's business name;

15.C.U. Permittee's air pennit number;

15.c.ii.(l) Identify which tank(s) will be degassed. Describe the size of the tank(s) and theproduct(s) in the tank;

15.c.ii.(2) The date or dates that degassing is expected to begin, and anticipated duration ofthe degassing operation; and

15.c.ii.(3) Terminal contact name and telephone number.

16. Risk Management Plan: Should this stationary source become subject to the accidental release preventionregulations in 40 CFR Part 68, then the permittee must submit a risk management plan (RMP) by the datespecified in 40 CFR 68.10 and comply with the plan and all other applicable Part 68 requirements. [40 CFRPart 68]



Table-II.

EU/PCD ID

BOILER

vcu

MLOAD/VCU

TRACK/VCU

TRACK/VRU-backup

INTANK

INTANKKB

FIXTANK

Emissions Unit Specific Emission Limits and Standards

Applicable Requirements

OAR / 40 CFR

340-208-0110

340-228-0210

40CFRSubpart Dc

340-208-0110

340-226-0210

340-232-0110

40 CFR 64.2

340-232-0090,§60.502(b)

40 CFR Part 64.2

340-232-0090

340-232-0150

40 CFR Part 60,

subpart Kb

340-232-0150(1)

Cond.

17

18

20

17

18

22

24

24

27

29

33

Pollutant/

Parameter

visibleemissions

PM/PMio

SulfurContent

visibleemissions

PM/PMio

voc

voc

voc

voc

voc

voc

voc

Limits/

Standards

20% Opacity,6-min block avg.

O.Mgr/dscf

0.5% by weight

20% Opacity,6-min block avg.

O.lOgr/dscf

5.7mg/Lor95%Control, O&MEquipment spec.

35 mg/L O&M,Equipment spec.

CAM

80 mg/L O&M,Equipment spec.

Equipment spec.

Equipment spec.

O&M req.

Monitoring Requirements

Method

VE periodicMonitoring


Testing &Recordkeeping



Testing, CPMS,I&M Record-keeping

Testing, I&MRecordkeepmg

CPMS

Testmg, I&MRecordkeepmg

Measurements,

I&M Recordkeeping

Measurements,

I&M Recordkeeping

Recordkeeping

Cond.

19

19

21

19

19

23

25

26

25

28

30-32

34

17. VISIBLE EMISSIONS STANDARD FOR BOILER & VCU The permittee must not cause or allow theemissions of any air contaminant into the atmosphere that is equal to or greater than 20% opacity,excluding uncombined water, from BOILER and VCU. Opacity must be measured in accordance withCondition 19, except as noted in Condition 19.h. [OAR 340-208-01 10]

18. PM/GRAIN LOADING LIMIT FOR BOILER & VCU The permittee must not cause or allow the emissionsofparticulate matter (PM) in excess of the following limits:

18.a. The PM emissions from BOILER must not exceed 0.14 grain per standard cubic foot, corrected to50% excess au-. [OAR 340-228-0210(2)(b)(B) & (3)(b)]

18.b. The PM emissions from VCU must not exceed 0.10 grain per standard cubic foot. [OAR 340-226-

0210(2)(c)]

19. MONITORAND RECORD Except as noted m Condition 19.h for BOILER, the permittee must monitorvisible emissions from the exhaust stack of BOILER and VCU in accordance with the following proceduresand frequencies:

19.a. At a minimum of once per week, except as noted in Condition 19.e, the permittee must conduct a

six (6) minute visible emission survey using the procedures outlined in EPA Method 22. The


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minimum weekly monitoring frequency specified is also the required interval between twoconsecutive monitoring periods.

19.b. All visible emissions observations must be conducted during period when the equipment isoperating.

19.c. If visible emissions, excluding condensed water vapor, are detected for more than 5% (18 seconds)of the survey time, an EPA Method 9 test must be conducted on that monitoring point for a six (6)minute period in accordance with the DEQ's Source Sampling Manual.

19.d. If, on a regularly scheduled test day, it is not possible to conduct an EPA Method 9 or 22 test dueto inclement weather conditions or interference from other fugitive sources, the permittee must

make three attempts during the day at approximately 10 a.m., noon, and 2 p.m. If it is still not

possible to conduct the test, the pennittee must perform the test the following day. The permitteemust record in a log the reason for not conducting the test on a regularly scheduled test day.

19.e. If visible surveys and/or observations conducted during 10 consecutive observation weeks show

no visible emissions, the permittee may stop visible emissions monitoring provided the VCUbums natural gas only as supplement fuel. Anytime an operator detects visible emission fromVCU, or when requested by the DEQ inspector, the visible emissions monitormg shall start overwith weekly surveys, as noted in item 19.a of this Condition.

19.f. RECORD: The permittee must maintain records of all visible emissions tests and surveys,

mcluding date, time, observer, observations, and results.

19.g. REPORT: A summary of exceedances noted during the visible emissions survey, if any, must be

included m the semi-annual report.

19.h. Exemption: As long as BOILER bums natural gas or LPG, the visual emissions survey requiredby this condition is waived. For the purpose of verification, the permittee must monitor and recordthe type(s) of fuel used in the BOILER, as specified in (NSPS) Condition 21.a.

20. NSPS FUEL OIL SULFUR CONTENT LlMITT FOR BOILER The permittee must not use any distillatefuel oils containing more than 0.5 percent sulfur by weight, on a 30-day rolling average basis. [40 CFR60.42c (d)]

21. NSPS MONITOR AND RECORD The permittee must monitor the amount and type of fuel burned inBOILER in accordance with the following methods and procedures:

21.a. The pennittee must monitor and maintain records of the amount and type of fuel combusted in

BOILER during each operating day. During any calendar month when only natural gas iscombusted, mamtain records of the amount ofNG burned during that calendar month. [40 CFR60.48c(g)]

21 .b. The permittee must analyze the oil sample to determine the sulfar content of the oil. Oil samplesmay be collected from the fuel-storage tank for BOILER after the fuel-storage tank is filled andbefore any oil is combusted in BOILER. If a partially empty fuel tank is refilled, a new sampleand analysis of the fuel in the tank would be required upon filling. Results of the fuel analysistaken after each new shipment of oil received must be used as the daily value when calculatmg the30-day rolling average until the next shipment is received.

If the fuel analysis shows that the sulfur content in the fuel tank is greater than 0.5 weight percentsulfur, the permittee must ensure that the sulfur content of subsequent oil shipments is low enoughto cause the 30-day rolling average sulfur content to be less than 0.5 weight percent sulfur. [40CFR 60.44c (g), 60.46c (d)(2)]


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21.c. In lieu of the fuel sampling method described in Condition 21.b, the permittee may demonstratecompliance based on fuel supplier certification that include the following information: [40 CFR60.44c(h),60.48c(f)(l)]

21 .c.i. The name of the fuel oil supplier; and21.c.ii. a certificate from the fuel oil supplier that confirms the fuel oil complies with the

distillate oil specifications and that contains less than 0.5% sulfar.

21 .d. All NSPS Records of this condition must be kept at the permitted facility for a period of two yearsfollowing the date of such record. [40 CFR 60.48c (i)]

22. REQUIREMENT FOR MLOAD The permittee must meet the following emissions standards andprovisions applicable to all marine loading operations (MLOAD) that transfer a liquid product identified initem 22.a into the marine tank vessels: [OAR 340-232-0110]

22.a. Liquid product means gasoline and the following volatile organic liquid (e.g., crude oil):

22.a.i. Any volatile organic liquid with a Reid vapor pressure (RVP) equal to or greater than27.6 KPa (4.0 psi); and

22.a.ii. any volatile organic liquid with a RVP equal to or greater than 20.7 KPa (3.0 psi) andpurposely heated to the liquid temperature of 110 degrees Fahrenheit or higher at thetime of loading.

22.b. Each loading berth at the marine terminal and all marine tank vessels used to transfer the regulatedliquid must be equipped with the vapor collection system capable ofcolletmg all displaced VOCvapors durmg the marine loading operations.

22.c. The VOC vapors that are displaced and collected durmg the marme loading operations must bereduced to at least 95 percent by weight, or limited to 5.7 grams per cubic meter (2 Ibs. per 1000bbls) of liquid loaded, as determined by EPA Method 25 or other methods approved in writing byDEQ.

22.d. The permittee must ensure that the following operation and maintenance (O&M) requirementsassociated with the marme loading operations are met:

22.d.i. All hatches, pressure relief valves, connections, gaugmg ports and vents associated

with the loading operations must be leak free and vapor tight.22.d.ii. Loading must cease anytime gas or liquid leaks are detected, and loadmg may resume

only after leaks are repaired. If the repair of leaking components is technicallyinfeasible without dry-docking the vessel or cannot otherwise be undertaken safely,submit documentation to the Department detailing the situation. Subsequent loadingevents involving the leaking components are prohibited until the leak is repaired.

22.cl.iii. Any liquid or gaseous leak detected by Department staff at any time is a violation ofthis condition.

22.e. Exemption: The following marine loading activities are exempt from the VOC controlrequirements of this condition, except as noted in Condition 22.e.iv:

22.e.i. Marine vessel bunkering;

22.e.ii. Loading any products other than the liquid identified in item 22.a into the vessel thathas been gas freed, regardless of the prior cargo; or


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22.e.iii. Lightering when neither vessel is berthed at a marme terminal dock, except duringCAA day as described in Condition 22.e.iv below.

22.e.iv. Lightering exempted from the control requirements by Condition 22-e.iii above must

be curtailed from 2:00 a.m. until 2:00 p.m. when the Department declares a Clean AirAction (CAA) day. If the Department declares a second CAA day before 2:00 p.m. ofthe first curtailment period, then such uncontrolled lightering must be curtailed for anadditional 24 hours until 2:00 p.m. on the second day. If a third CAA day in a row isdeclared, then uncontrolled lightering is permissible for a 12-hour period starting at 2p.m. on the second CAA day and ending at 2 a.m. on the thkd CAA day.

Uncontrolled lightering must be curtailed from 2 a.m. until 2 p.m. on the third CAAday. If the Department contmues to declare CAA days consecutively after the thirdday, the curtailment and loading pattern used for the third CAA day will apply.

23. MONITOR AND RECORD For the VOC emission standard and O&M requirements applicable to MLOAD,as specified in Condition 22, the permittee must conduct the required inspection and testmg in accordancewith the following procedures and frequency:

23.a. The permittee must determine compliance with the VOC mass emission limitation (5.7 mg/L) orthe 95% VOC reduction limit of Condition 22.c by testing within one year from the VCUinstallation date and every three years thereafter, in accordance with EPA Method 25A or 25B orother methods approved in writing by the DEQ.

23.a.i. The exhaust stack of the VCU must be designed and configured to comply withEPA's test Method 1 and appropriately equipped with sample ports for sample andvelocity traverses while source testing.

23.a.ii. Determine the minimum operating temperature, based on a one hour average,

required to meet the 5.7 mg/L or 95% reduction standard.

23.b. Any marine tank vessel used to transfer the regulated liquid identified in item 22.a must becertified on an annual basis that the vessel is leak free, vapor tight, and in good working order,using EPA Method 21 or other methods approved in writing by the DEQ. The permittee mustmaintain records of all marine vessels that loaded the regulated liquid at the permitted facility, andthe record-file must include at minimum the following information on each marine vessel:

23 .b.i. Marine vessel owner and address;

23.b.ii. vessel identification number;

23 .b.iii. leak test Method used, if other than EPA Method 21;23.b.iv. testing location and date of test;

23.b.v. tester name, signature, and affiliation;

23.b.vi. a summary of test results; and

23.b.vii. update the file, as often as possible, but at least once per year to reflect the marine

vessel certification-status.

23 .c. The pennittee must maintain the operating records of each loading event. Monitor and record at

minimum the following information:

23.C.L The location of each loading event.

23.C.U. The date of arrival and departure of the vessel.

23 .c.iii. The name, registry and legal owner of each marine tank vessel participating in the

loading event.

23.c.iv. The type and amount of liquid product loaded into the marine tank vessel.

23.C.V. The prior cargo carried by the marine tank vessel. If the marine tank vessel has been

gas freed, then the prior cargo can be recorded as gas freed.

23.c.vi. The description of any gaseous or liquid leak, date and time of leak detection, leakrepau- action taken and screening level after completion of the leak repair.


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24. REQUIREMENT FOR TRACKA^CU The permittee must meet the following emissions standards andprovisions applicable to all the loading racks existing at the permitted facility that transfer gasolineproducts into the delivery tanks and trailers: [OAR 340-232-0090 and 340-232-0100]

24.a. The loading racks must be equipped with the vapor collection and control system designed to meetthe following criteria:

24.a.i. Requu-ement applicable to VCU: The total volatile organic compound (VOC)emissions from the loading operations must not exceed 35 milligrams ofVOC perliter of gasoline loaded (292 Ib VOC/106 gal gasoline loaded);

24.a.ii. Requirement applicable to VRU: In lieu of the 35 mg/L limit specified in Condition24.a.i, when a backup unit VRU is operated in place ofVCU, the total VOCemissions from the loading operations must not exceed 80 milligrams ofVOC perliter of gasoline loaded (668 Ib VOC/106 gal gasoline loaded);

24.a.iii. all organic vapors displaced fi-om the gasoline delivery tanks and trailers duringproduct loading are collected and vented to the vapor control system only;

24.a.iv. each vapor collection system must be designed to prevent any total organic

compounds vapors collected at one loading rack from passing to another loading rack;and

24.a.v. all vapor lines have fittings which make vapor-tight connections and which close

automatically and immediately when disconnected.

24.b. Loadmg gasoline products into the delivery tanks and trailers must be limited to the certifiedvapor-tight tanks and trailers, as verified from one of the following:

24.b.i. A current Oregon leak test certification form for the delivery vessel is on file at theterminal; or

24.b.ii. a valid Oregon delivery vessel certification sticker, as specified in OAR 340-232-100(l)(c), is clearly displayed on the delivery vessel.

24.c. The permittee must ensure that the following operation and maintenance (O&M) requirementsassociated with the gasoline loading operations are met:

24.c.i. The vapor collection and liquid loading equipment must be operated m a manner toprevent gauge pressure in the delivery tank from exceeding 4,500 Pascal (18 inches ofEhO) and vacuum from exceeding 1,500 Pa (6 in H20) durmg product loading;

24.c.ii. no gasoline shall be loaded into the delivery vessel unless the vessel is equipped to becompatible with the terminal's vapor collection system, and vapor return hose isproperly connected;

24.c.iii. allow no more than 10 cubic centimeters (cm3) dramage per disconnect on the basis of5 consecutive disconnects;

24.c.iv. ensure no visible liquid gasoline leaks during the loading operations; and24.C.V. if more than five (5) gallons are spilled, the permittee must report the spillage in

accordance with Condition 53, the excess emissions reporting requirements.

25. MONITOR AND RECORD For the VOC emissions standards applicable to TRACK, as specified inCondition 24, the permittee must conduct the required inspection and testing in accordance with thefollowing procedures and frequency:

25.a. The permittee must determine compliance with the mass emission limitation (35 mg/L) ofCondition 24.a.i by testing within 12-month from the date of the VCU installation and every threeyears thereafter, in accordance with EPA Method 25A; the methods and procedures delineated in


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40 CFR 60.503, subpart XX, as summarized in Attachment 1 of this permit; or an alternativemethod (e.g., EPA Method 25B) approved in writing by the DEQ.

25.a.i. The exhaust stack of the VCU must be designed and configured to comply withEPA's test Method 1 and appropriately equipped with sample ports for sample andvelocity traverses while source testing.

25.a.ii. Determine the minimum operating temperature, based on a one hour average,

required to meet the 35 mg/L standard.

25.b. The permittee must have the means (e.g. physical inspection) to show or keep readily accessiblerecords showing the TRACK meets the design specifications of Conditions 24.a.iii through 24.a.vof this permit.

25.c. The pemiittee must determine compliance with Condition 24.c.i by testing, which shall coincidewith the compliance testing conducted per Condition 25.a, in accordance with the followingmethods and procedures:

25.C.L Using a pressure measurement device (liquid manometer, magnehelic gauge, or

equivalent instrument) capable of measuring up to 500 millimeters (mm [20 inches])of water gauge pressure with the ±2.5 mm HbO precision;

25.c.ii. measure and record the gauge pressure in the gasoline tank being loaded byconnecting the pressure measurement device to a pressure tap in the terminal's vapor

collection system, located as close as possible to the connection with the gasoline tanktruck.

25.c.iii. Record the pressure at 5 minute interval while a gasoline tank truck is being loaded,and record the highest instantaneous pressure that occurs during loading.

25.c.iv. Every loading position must be tested at least once during the performance test.

25.d. At a minimum of once per month, the permittee must inspect the vapor collection system, the

vapor control system, and each loading rack for liquid and vapor leaks during product transferoperations. For purpose of this inspection, detection methods incorporatmg sight, sound, or smellare acceptable. Each detection of leak must be recorded and the source of the leak repaired within15 calendar days after it is detected. The pennittee must maintain the records of this inspection,and mclude, at minimum, the following information:

25.d.i. date ofmspection;

25.ci.ii. findings - location, nature, and severity of each leak, or indicate no leaks;

25.ci.iii. leak determination method; and25.d.iv. corrective action taken - record date each leak repaired and provide reason for any

repair interval in excess of 15 days, as applicable.

25.e. The permittee must maintain records of current leak test certifications for all the delivery vesselsloading gasoline at the permitted facility, as required per Condition 24.b, and the file must includeat minimum the following information on each delivery vessel:

25.e.i. tank owner and address;

25.e.ii. tank identification number;25.e.iii. tester name, signature, and affiliation;

25.e.iv. test Method used;

25.e.v. testing location and date of test;

25.e.vi. test results: actual pressure change (mm HiO) m 5 minutes, average of two runs; and

25.e.vii. update the documentation file, as often as possible, but at least once per year to reflect

the delivery vessel status.

25.f. The permittee must require the tank identification number to be recorded as each gasoline tanktruck is loaded at the terminal.


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25.g. The permittee must crosscheck each tank identification number obtained in item 25.f with thepermittee's file as maintained per item 25.e within 2 weeks after the corresponding tank is loaded.If any discrepancy is noted, the permittee must take corrective steps necessary:

25.g.i. Notify the owner or operator of each non-vapor tight gasoline tank truck, within 3

weeks after the loading has occurred; and25.g.ii. take steps assuring the non-vapor tight gasoline tank truck will not be reloaded at the

facility until vapor lightness documentation for that tank is obtained from the cargotank owner.

25 .h. The permittee may use alternative procedures to those specified in Conditions 25.e through 25.g,upon written application to, and approved in writing by the Department.

26. COMPLIANCE ASSURANCE MONITORING REpmREMENT FOR VCU ForVOC emissions standardsapplicable to truck/trailer loading (TRACKA^CU) and marine loadmg (MLOADA/'CU) operations, ofwhich a single VOC abatement device (VCU) is utilized, the permittee must continuously monitor andrecord the combustion temperature ofVCU in accordance with the following procedures and frequency:

26.a. To ensure compliance with all of the VOC emissions standards applicable to VCU or VRU, assummarized in items 26.a.i to 26.a.iii below, the CAM requirements must be based on the most

stringent VOC standard (i.e., 5.7 g/m3) whenever VCU is utilized to abate VOC emissions fromMLOAD:

26.a.i. 5.7 milligrams ofVOC per liter ofgasolineA^OL, or 95% by weight reduction ofVOC inlet, applicable to MLOADWCU, as specified in Condition 22.c;

26.a.ii. 35 milligrams ofVOC per liter of gasoline loaded applicable to TRACKA/'CU, asspecified in Condition 24.a.i; and

26.a.iii. 80 milligrams ofVOC per liter of gasoline loaded applicable to TRACKVVRU, asspecified in Conditions 36.a, until VRU is replaced with VCU.

26.b. Continuous monitoring system (CPMS) capable of measuring temperature must be installed in thefirebox or m the ductwork immediately downstream from the firebox in a position before anysubstantial heat exchange (if any) occurs.

26.c. Continuously record the temperature on a strip/cu-cular chart or in electronic files and compare the

VCU temperature readings to the minimum temperature requked to meet the VOC emissionscontrol standard of Condition 26.a.i or 26.a.ii as determined through source testing performed perCondition 23.a.

26.d. The vapor combustor's combustion chamber shall be configured to operate with logic controls setto close the block valve to receiving vapors if the operatmg temperature does not reach a minimumtemperature needed in 26.a within 10 minutes.

26.e. When loadmg operation bypasses the vapor bladder and VCU operatmg temperature does notreach a minimum temperature needed in 26. a within 10 minutes, an alarm system will trigger andsuspend the loading operation until the problem is fixed.

26.f. Record all inspections and mamtenance performed on VCU.

26.g. The following apply only when a backup unit VRU is operated:26.g.i. Continuously record the VOC outlet concentration, which is based on 30-minute

rolling average, on a strip or circular chart, or other recording device approved by theDEQ.

26.g.ii. Calibrate the GEM (VOC analyzer) quarterly in accordance with the CEMmanufacturer's specifications.


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26.g.iii. Set the alarm on VRU to trigger when VOC concentration reaches 4% by volume(corresponding to -80 mg/L VOC) based on 30-minute rolling average, and the truckloading rack will shut down and stop the gasoline loading operations.

27. REQUIREMENT FOR INTANK Except as provided Condition 27.g, the internal floating roof storagetanks (INTANK) must be equipped with a fixed roof with an internal floating type cover, and meet thefollowing equipment standards and provisions: [OAR 340-232-0150]

27.a. The internal floating cover must be equipped with a continuous closure device (primary seal)between the tank wall and the cover edge.

27.b. The internal floating roof must be floating on the liquid surface at all times, except during initialfill and during intervals when the storage vessel is completely emptied or subsequently emptiedand refilled. During the period the roof is resting on the leg supports, the process of filling,emptymg, or refilling must be continuous and must be accomplished as rapidly as possible.

27.c. Each opening in the cover except for automatic bleeder vents and the rim space vents is to be

provided a projection below the liquid surface.

27.d. Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rimspace vents, stub drains and leg sleeves is to be equipped with a cover, seal, or lid which is to bemaintained in a closed position at all times (i.e., no visible gap) except when the device is in actualuse.

27.e. Automatic bleeder vents are to be closed at all times when the roof is floatmg except when theroof is being floated off or is being landed on the roof leg supports.

27.f. Rim vents are to be set to open only when the internal floating roof is not floating or at themanufacturer's recommended setting.

27.g. Any storage tank grouped under INTANK storing VOL with a true vapor pressure of less than 1.5psia at the storage temperature is exempted from the requirements of this condition and theassociated monitoring specified in Condition 28.

28. MONITOR AND RECORD For the equipment specifications applicable to INTANK, as outlined inCondition 27, the permittee must conduct the visual inspection in accordance with the following proceduresand frequency:

28.a. At a minimum of once every 12 months, the permittee must conduct visual and other inspections

necessary to ensure all the tank parts are functionmg properly, as outlined in Condition 27.bthrough 27.f.

28.b. Each time the vessel is emptied and degassed, prior to filling the storage vessel with VOL,visually inspect the primary seal, and/or the secondary seal if one is in service, of the internalfloating roof. If there are holes, tears, or other openings and/or defects in the seal or the seal fabricof the internal floating roof, the pennittee must repair the items before filling the storage vessel.

28.c. The permittee must record in a log the date of the inspection, the result of the inspection, and thecorrective actions taken, if any.


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29. REQUIREMENT FOR INTANKKB The FNTANKKB identified in Condition 5 must comply with therequirements of 40 CFR, Subpart Kb - "Standards of Performance for Volatile Organic Liquid StorageVessels", except as relieved by Condition 29.]: [40 CFR 60.112b(a)(l)]

29.a. Internal floating roof must be equipped with one of the following closure devices between the wallof the vessel and the edge of the internal floating roof:

29.a.i. A foam-filled or liquid-filled seal mounted m contact with the liquid (i.e. liquid-mounted seal);

29.a.ii. a mechanical shoe seal; or

29.a.iii. two seals mounted one above the other so that each forms a continuous closure that

completely covers the space between the wall of the storage vessel and the edge of theinternal floating roof. The lower seal may be vapor-mounted, but both must becontmuous.

29.b. The internal floatmg roof must be floating on the liquid surface at all times, except durmg initialfill and during intervals when the storage vessel is completely emptied or subsequently emptiedand refilled. During the period the roof is resting on the leg supports, the process of filling,emptying, or refilling shall be continuous and accomplished as rapidly as possible.

29.c. Each openmg in a non-contact internal floating roof except for automatic bleeder vents (vacuum

breaker vents) and the rim space vents is to be provided a projection below the liquid surface.

29.d. Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rimspace vents, column wells, ladder wells, sample wells, and stub drains is to be equipped with acover or lid which is to be maintained m a closed position at all times (i.e., no visible gap) exceptwhen the device is in actual use. The cover or lid must be equipped with a gasket. Covers andeach access hatch and automatic gauge float well must be bolted except when they are in use.

29.e. Automatic bleeder vents must be equipped with a gasket and are to be closed at all times when theroof is floating except when the roof is being floated off or is being landed on the roof legsupports.

29.f. Rim space vents must be equipped with a gasket and are to be set to open only when the internalfloating roof is not floating or at the manufacturer's recommended setting.

29.g. Each penetration of the internal floating roof for the purpose of sampling must be a sample well.The sample well shall have a slit fabric cover that covers at least 90 percent of the opening.

29.h. Each penetration of the internal floating roof that allows for passage of a column supporting thefixed roof shall have a flexible fabric sleeve seal or a gasketed sliding cover.

29.i. Each penetration of the internal floating roof that allows for passage of a ladder shall have agasketed sliding cover.

29.]. Exemption: Any INTANK-KB with a storage capacity greater than or equal to 151 m3 (39,890gallons) that stores VOL with a true vapor pressure of less than 3.5 KPa (0.5 psi) at the storagetemperature; or any INTANK-KB with a storage capacity greater than 75 m3 (19,813 gallons) butless than 151m3 (39,890 gallons) that stores VOL with a true vapor pressure of less than 15 KPa(2.2 psi) at the storage temperature; or any FNTANK.KB with a storage capacity less than 75 m3(19,813 gallons) is exempt from the requirements of this condition and the associated monitoring,recordkeeping, and reportmg requirements specified in Conditions 30 through 32 excludingCondition 31.a. [40 CFR 60.112b (b) & (c)]

29.k. For the exempt INTANKKB identified in Condition 29.], the permittee must monitor and maintainrecords of the following product information: [40 CFR, 60.116b (c)]


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29.k.i. type of products stored in each tank; and

29.k.ii. the maximum vapor pressure of that product stored during the respective storage

period.

29.1. Notify: For the exempt INTANK.KB identified in Condition 29.], when the maximum true vaporpressure ofVOL stored in the INTANK.KB (see Condition 5) with a storage capacity greater thanor equal to 151 m3 (39,890 gallons) exceeds 5.2 KPa (0.75 psi); or when the maximum true vaporpressure ofVOL stored in INTANI<KB with a storage capacity greater than 75 m3 (19,813 gallons)but less than 151m3 (39,890 gallons) exceeds 27.6 KPa (4.0 psi), the permittee must notify theDepartment within 30 days. [40 CFR, 60.116b (d)]

30. NSPS, Subpart Kb Monitorins: For INTANK-KB identified m Condition 5, the permittee must conductthe required inspection and testmg in accordance with the following procedures and Irequency:

30.a. Prior to filling the storage vessel with VOL, visually inspect the primary seal and the secondaryseal (if one is in service) of the internal floating roof. If there are holes, tears, or other openingsand/or defects in the seal or the seal fabric of the internal floating roof, the permittee must repairthe items before filling the storage vessel.

30.b. For vessels equipped with a liquid-mounted primary seal per Condition 29.a.i or a mechanicalshoe primary seal per Condition 29.a.ii, the permittee must visually inspect the internal floatingroof and the primary seal or the secondary seal (if one is in service) through manholes and roofhatches on the fixed roof at least once every 12 months after initial fill:

30.b.i. If the internal floating roof is not resting on the VOL surface, or there is VOLaccumulated on the roof, or the seal is detached, or there are holes, tears, or other

openings in the seal fabric, the pennittee must repair the defects or empty and removethe storage vessel from service within 45 days of identification of defects.

SO.b.ii. If the defects cannot be repaired or the vessel cannot be emptied within 45 days, thepermittee may request for a 30-day extension in the written report required perCondition 32.b. Such extension request must include, but not limited to, ademonstration ofunavailability of alternate storage capacity and a specification or aschedule that will assure that the control equipment will be repaired or the vessel willbe emptied as soon as possible.

30.c. For vessels equipped with a double-seal system as specified in Condition 29.a.iii, the permitteemust visually inspect the vessel in accordance with one of the following methods/procedures:

30.c.i. On an annual basis, conduct the visual inspection as specified in Condition 30.b; and

30.c.ii. at least once every 10 years, visually inspect the internal floating roof, the primaryseal, the secondary seal (if one is in service), gaskets, and slotted membranes and

sleeve seals (if any).If the internal floating roof has defects; primary or secondary (if one is in service) sealhas holes, tears, or other openings in the seal or seal fabric; the gaskets no longerclose off the liquid surfaces from the atmosphere; and/or the slotted membrane hasmore than 10 percent open area, the permittee must repair all the noted defects beforerefilling the storage vessel with VOL.

30.d. Notify: The permittee must notify the Department Northwest Region in writing at least 30 daysprior to filling or refilling of each storage vessel for which an inspection is conducted perCondition 30.a or 30.c.ii, and provide the Department inspector an opportunity to observe. If theinspection conducted per Condition 30-c.ii cannot be planned 30 days in advance, the permitteemust notify the Department, at least 7 days prior to refilling the vessel, via telephone immediately


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followed by a written notification via express mail so that the notification is received by theDepartment at least 7 days prior to the refilling.

31. NSPS,Subpart Kb, Recordkeeping: For INTANK.KB identified in Condition 5, the permittee mustadhere to the following recordkeeping requirements:

31 .a. The permittee must keep records showing the dimension of the storage vessel and an analysis

showing the capacity of each INTANI<KB. These records must be kept for the life of the source.[40 CFR, 60.116b(a)/(b)]

31 .b. The permittee must keep the following record of each mspection performed per Condition 3 0:[40CFR60.115b(a)(2)]

31 .b.i. storage vessel ID

31 .b.ii. date of the inspection

31.b.iii. the observed Condition of each component of the equipment inspected (e.g., seals,

internal floating roof, and fittings)

31 .c. The permittee must maintain records of dates the storage vessels were emptied and refilled; and

monitor and record the following product information:

31 .c.i. type of products stored in each tank; and

31 .c.ii. the maximum true vapor pressure of that product during the respective storage period.

32. NSPS, Subpart Kb, Reportine: For (future project) INTANK.KB identified in Condition 5, once the unitis modified and become subject to meeting the equipment specifications outlined in Condition 29, thepermittee must adhere to the following reporting requirements:

32.a. After installing an internal floating roof, submit a written report certifying that the storage tankmeets the specifications outlined in Conditions 29 and 30.a. [40 CFR 60.115b(a)(l)]

32.b. If any defects are detected during the inspection conducted per Condition 30.b or 30.c, thepermittee must provide a written report to the Department within 30 days of the inspection,identifying the storage vessel, the nature of the defects and the date the storage vessel was emptiedor the nature of and date the repau- was made. [40 CFR 60.115b (3)/(4)]

33. REQUIREMENT FOR FlXTANK All fixed roof storage tanks grouped under FIXTANK having a storagecapacity greater than 39,000 gallons must not store Volatile Organic Compound Liquids (VOL) with a truevapor pressure, as stored, greater than 1.52 psia at actual monthly average storage temperature. [OAR 340-

232-0150(1)]

34. MONITOR AND RECORD For the purpose of demonstrating compliance with Condition 33, the permitteemust keep records of all products stored in the fixed roof storage tank with a capacity greater than 39,000gallons. [Note that the PSEL monitoring protocols for FIXTANK already satisfies the recordkeepingrequu-ements of this condition.]


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Table-III.

EU/PCD ID

FIXTANK

INTANK

1

TRACK7VRU

PIPES

NESHAP Subpart 6B Requirements

Applicable Requirements

OAR/40CFR

40 CFR, Part 63,

63.11087

40 CFR, Part 63,

63.11088

40 CFR, Part 63,

63.11089

Cond No.

35

36

37

Pollutant/

Parameter

voc/VOHAP

voc/VOHAP

voc/VOHAP

Limits/

Standards

Equipment-

Specifications

80 mg/1, O&M,

Equipment-

Specifications

No leak (i.e.,

< 500 ppmv)

Monitoring Requirements

Method

Measurements,

I&MRecordkeeping

Testing, I&MRecordkeeping

CAM

Testing, I&MRecordkeeping

Cond No.

34,28,

30-32

25

26

37

3 5. NESHAP SUBPART BBBBBB f6B) REQUIREMENTS FOR STORAGE TANKS: The permittee mustcomply with the following requirements applicable to storage tanks by no later than January 10, 2011. [40CFR 63.11083 (b), 63.11087]

35.a. FIXTANK: Fixed Roof Storage Tanks (i.e., FDCTANK identified in Condition 3.a with thecapacity greater than 75 cubic meters (19,813 gal) are strictly prohibited from storing gasoline.FIXTANK with the capacity less than 75 m3 must maintain all openings in a closed position at alltimes when not in use. [§63.11087(a)]

35.b. INTANK & INTANKKB: Internal Floating Roof Storage Tanks (i.e., mTANK identifiedin Condition 3.b, and INTANKicB identified in Condition 5 that ah-eady meet the requu-ementsspecified m Conditions 27 through 32 are deemed in compliance with the area source NESHAPsubpart-6B requirements applicable to INTANK and WTANKKB. The permittee must submit theNotification of Compliance Status Report as specified in Condition 38 below. [§63.11087(f)]

35.c. Testmg and Monitoring Requirements are specified in §63.11092(e) and they are same as themonitoring specified in this permit for storage tanks. The permittee must adhere to the testing andmonitoring protocols of Conditions 28 for FNTANK, and Condition 30 for INTANKKB.

35.d. • Recordkeeping Requirements are specified in §63.11094(a) and they are same as therecordkeeping specified in this permit for storage tanks. The permittee must adhere to therecordkeeping requirements applicable to gasoline storage tanks FDCTANK and INTANK.

3 5.e. Reporting Requirements are specified in §63.11095 and they are same as the reportingrequirements specified in this permit. The permittee must adhere to the reporting requirementsapplicable to gasoline storage tanks FIXTANK and INTANK, and submit required informationwith annual or semi-annual report submitted per Condition 57.

35.f. Notifications required as specified in Condition 38 below. [§63.11087(f)]

3 6. NESHAP SUBPART BBBBBB (6B) REQUIREMENTS FOR TRUCK/TRAILER LOADING RACKS : Thepermittee must comply with the following requkements applicable to Truck/Trailer Loadmg Racks(TRACK) by no later than January 10,2011. [40 CFR 63.11083 (b), 63.11088]

36.a. Volatile organic compound (VOC) emissions from Tanker Truck and Trailer Loading Racks (i.e.,TRACK identified m Condition 3.d) must not exceed 80 milligrams ofVOC per liter of gasolineloaded. The TRACK that already meet the VOC emissions limits specified in Conditions 24.a.i



(80 mg /L) is deemed in compliance with the 80 mg/L VOC emissions standard of area sourceNESHAP subpart-6B requirements applicable to truck loading racks.

36.b. Testing and Monitoring Requirements are specified in §63.11 092 are same as the monitoringspecified in this permit for TRACK, except as noted below. The permittee must adhere to thetesting and monitoring protocols of Condition 25 except as follows:

36.b.i. Use the test methods and procedures outlined m Condition 25 and Attachment-1 ofthis permit, except a reading of 500 ppm m lieu of 10,000 ppm must be used todetermine the level of leaks to be repaired. [§63.11092(a)(l)(i)]

36.b.ii. The permittee must continuously monitor the VOC concentration ofVRU outlet asspecified in Condition 26 of this permit. [§63.11092(b)(l)(i)(A)]

36.c. Recordkeeping Requirements are specified in §63.11094(b) and they are same as therecordkeeping specified in this permit for TRACK. The permittee must adhere to therecordkeeping requirements applicable to Truck/trailer loadmg racks.

As an alternative to keeping records at the facility for each gasoline cargo tank test results, thepermittee can utilize automated system (e.g., card lock-out system) to prevent gasoline cargo tanks

that do not have valid cargo tank vapor tightness documentation from loading. [§63.11094(c)(2)]

36.d. Reporting Requirements are specified in §63.11095 and they are same as the reportingrequirements specified in this permit. The permittee must adhere to the reporting requirementsapplicable to truck/trailer loadmg racks TRACK, and submit required information with annual orsemi-annual report submitted per Condition 57.

36.e. Notifications Required as specified in Condition 38 below. [§63.11087(f)]

37. NESHAP SUBPART BBBBBB f6B) MONITORING REQUIREMENTS FOR EQUIPMENT LEAKS: Thepermittee must comply with the following equipment leak-inspection requirements applicable to TRACKand all other "equipment" in gasoline service by no later than January 10,2011. [40 CFR 63.11083 (b),63.11089]

37.a. As defined in §63 .11100, "equipment" means each valve, pump, pressure relief device, sampling

connection system, open-ended valve or line, and flange or other connector in the gasoline liquid

transfer and vapor collection systems. The equipment also includes the entire vapor processing

system excluding the exhaust ports or stacks.

3 7.b. The permittee must conduct the equipment leak inspection on a monthly basis. As with leak-inspections conducted on TRACK per Condition 25.d, detection methods incoiporating sight,sound, and smell are acceptable for this inspection.

37.c. The permittee must keep a log book and record the summary of findings of each inspection, andeach inspection must be signed off by the inspector or responsible official.

37.c.i. Prepare and maintain a record for each equipment in gasoline service by types,

identification numbers, and locations.

37.c.ii. A section of the log book shall contain a list, summary description, or diagram

showing the location of all equipment in gasoline service at the facility.

37.d. If the leak is detected, the permittee must make an attempt to repair the leak as soon as practicablebut no later than 5 calendar days after the leak is detected. Repair or replacement of leakingcomponent must be completed within 15 calendar days after detection of each leak unless such


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repair is not feasible within 15-days, in which case the semi-compliance certification must includethe reasons for delay and the date each repair was completed.

37.e. For each leak detected, the following information shall be recorded in the log book:

37.e.i. The equipment type and identification number;37.e.ii. The nature of the leak (i.e., vapor or liquid) and the actual method of detection (i.e.,

sight, sound, smell, and/or instrument reading);37.e.iii. The date the leak was detected and the date each attempt to repair the leak;37.e.iv. Repau' methods applied iu each attempt to repair the leak;37.e.v. "Repair delayed" and the reason for the delay if the leak is not repaired within 15

calendar days after discovery of the leak;37.e.vi. The expected date of successful repau- of the leak if the leak is not repaired within 15

days; and37.e.vii. The date of successful repair of the leak.

37.f. Reporting Requirements: Report the number of equipment leaks not repaired within 15 days afterdetection, if any, in the excess emissions report mcluded with the annual or semi-annual report

submitted per Condition 57.

37.g. Notifications Required as specified in Condition 3 8 below. [§63.11087(f)]

38. Notification Requirements;

38.a. Notification of Compliance Status: The permittee must submit the Notification of ComplianceStatus Report as specified in 63.11093(b), which may coincide with the semi-annual compliancecertification submitted per Condition 57. The Notification of Compliance Status must include thetype/methods used to comply with each of the applicable NESHAP subpart-6B requirementsspecified in Conditions 35, 36, and 37.

38.b. Notification of Performance Test: The permittee must submit a Notification of Performance Test,as specified in §63.9(e), prior to initiating testing reqmred by §63.11092(a) or §63.11092(b).

Note: The source test plan submitted to the Department per Condition 45 satisfies the"Notification of Performance Test" requu'ement of this condition.

38.c. Semi-annual Excess Emissions Report: The pennittee must submit an excess emissions report as

specified m 63.11095(b), at the same time when semi-annual compliance certifications aresubmitted per Condition 57. If no excess emission events have occurred during the previous 6-month period, no report is required. Semi-annual Excess Emissions Report submitted under63.11095(b) must include the following information:

38.c.i. Each instance of a non-vapor-tight gasoline cargo tank loading at the facility in whichthe owner or operator failed to take steps to assure that such cargo tank would not bereloaded at the facility before vapor tightness documentation for that cargo tank wasobtained.

38.c.ii. Each reloading of a non-vapor-tight gasoline cargo tank at the facility before vaportightness documentation for that cargo tank is obtained by the facility in accordancewith Condition 25.g.

38.c.iii. Each exceedance or failure to maintain, as appropriate, the monitored operating

parameter value (i.e., CMS data) determined under Condition 26. The report shallinclude the monitoring data for the days on which exceedance or failures to maintain



have occurred, and a description and timing of the steps taken to repair or performmaintenance on the vapor collection and processing systems or the CMS.

38.c.iv. For each occurrence of an equipment (as defined in Condition 37.a) leak for which norepair attempt was made within 5 days or for which repair was not completed within15 days after detection:

(i) The date on which the leak was detected;(ii) The date of each attempt to repair the leak;(iii) The reasons for the delay of repair; and(iv) The date of successful repair.

Emission Limits and Standards applicable to Insignificant Activities

39. DEQ acknowledges that insignificant emissions units (lEUs) identified by rule as either categoricallyinsignificant activities or aggregate insignificant emissions as defined in OAR 340-200-0020 exist atfacilities required to obtain an Oregon Title V Operating Permit. lEUs must comply with all applicablerequirements. In general, the requirements that could apply to lEUs are incorporated as follows:

39.a. OAR 340-208-0110 (< 20% opacity, 3 min.)39.b. OAR 340-228-0210 (0.10 gr/dscf corrected to 12% 002 or 50% excess air for fuel burning

equipment)39.c. OAR 340-226-0210 (0.10 gr/dscffor non-fagitive, non-fuel burning equipment)39.d. OAR 340-208-0210 (Fugitive dust control)39.e. OAR 340-208-0450 (No offsite deposit ofPM > 250 micron)

Unless otherwise specified m this permit or an applicable requirement, DEQ is not requiring any testing,monitoring, recordkeeping, or reporting for the applicable emissions limits and standards that apply tolEUs. However, if testing were performed for compliance purposes, the permittee would be required to use

the test methods identified in the definitions of'opacity" and "particulate matter" in OAR 340-208-0010and perform the testing in accordance with DEQ's Source Sampling Manual.


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PLANT SITE EMISSION LIMITS

40.

41.

42.

43.

ANNUAL PSEL REQUIREMENT The permittee must not exceed the following annual plant siteemissions based on 12-month rolling average (tons/year): [OAR 340-222-0020 and 340-222-0040/41]

EUID

Plant-wide Total

PM2.5

9

PMio

14

S02

39

NOx

39

co

99

voc

163

The annual plant site emissions limits apply to any 12-consecutive calendar month period; meaning theannual emissions for the previous 12-month period must be calculated at the end of each calendar month,for a total of 12 times during the calendar year.

MONITOR AND RECORD FOR PSEL: The permittee must determine compliance with the annual PSELspecified in Condition 40 by conducting monitoring in accordance with the procedures and frequenciesspecified in Conditions 41 through 43. The permittee must monitor and record the following material andprocess parameters on a monthly basis:

EMISSIONS UNITMLOADTRACKFIXTANK

INTANK

PIPES

BOILER

vcu

OPERATING PARAMETERThroughput of each organic liquid product

Throughput of each organic liquid product

Throughput of each organic liquid productfrom each storage tank.

Throughput of each organic liquid productfrom each storage tank.

VOC emissions from Flanges, valves,pumps, etc. at Terminal

Natural gas usageDistillate Fuel oil usage

Natural gas usage

UNITGallons

Gallons

Gallons

Gallons

Number ofComponents

106ft3NG103 gallons106ft3NG

METHODRecordkeeping

Recordkeeping

Recordkeeping

Recordkeepmg

Recordkeeping

Recordkeeping

Recordkeeping

BOILER & VCU: At the end of each month, calculate the annual emissions (i.e., emissions during theprevious 12-month period) of each regulated criteria pollutant from BOILER and VCU by using theoperating parameters (e.g., fuel usage) obtained in Condition 41 and applymg to the formula and theemissions factors provided below:

Ej = Zprevious 12-mo (Pi EFjj) = (Pl EFj.l) + (P2 EFj,2)

where: Ej = pollutant "j" emissions; tons/year.

Pi = operating parameter identified in Condition 41; diesel or natural gas.EFjj = emission factor identified for each fuel type and pollutant listed in Table below.

EUID

BOILER

vcu

FUEL

Diesel

Natural gas

Natural gas

PM10(2)

2

7.6

2.5 x 10-3

S02

142(%S) W

0.6

2.6 x 10-3

NOx

14.3

50

1 x 10-1

co

5.4

84

8.4 xl0-2

voc

0.2

5.5

-(3).

UNIT

lbs/103 gal

lbs/106ft3

Ibs/MMBtu

(1) S02 EF for dist. oil is a ftinction of%S, obtained per monitoring Condition 8 or 21.

(2) Emissions of fine particulate matter, PMi.s is equal to PMio emissions by default, until proven otherwise.(3) VOC emissions from TRACK & MLOAD calculated per monitoring Conditions 43.c and 43.d.

VOC EUs: At the end of each month, the permittee must calculate the annual (i.e., previous 12-month

period) VOC emissions from emissions units FIXTANK, INTANK, MLOAD, TRACK, and PIPE using the


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throughput data for EU identified in 41 and the algorithms provided below: [Ref. "Air PollutionEngineering Manual", Air & Waste Management Association, Chapter 9 - Evaporative Loss from

Petroleum Storage]

EVOC = ^previous 12-mo Ej

where: Evoc = Plant-wide annual VOC emissions; and

Ej = Annual VOC emissions from emissions unit EU; specified.

43.a. Except as provided in Condition 43.f, VOC emissions from each fixed roof storage tank groupedunder the emissions unit FIXTANK shall be calculated based on the following algorithms:

(1) LFIXTANK = Total loss = LB + Lw (Ibs/yr)

LB= fixed roof breathing loss = 2.26xl0-2 My [ P/(PA - P)]0-68 D'-73 H°-51 AT0-5 Fp C Kc

Lw = fixed roof workmg loss = 2.4xl0-5 MyP VN KN Kc

where: My = average vapor molecular weight

P = true vapor pressure at bulk liquid conditions, psia; see TABLE-2, Attachment 2PA = average atmospheric pressure at tank location, psia; default = 14.7 psiD = tank diameter, feet

H = average vapor space height - if not available, assume H equals 1/2 the tank height.

AT = average ambient diurnal temperature change, °F; default = 15°F (assumption)Fp = paint factor; see TABLE-1, Attachment 2C = adjustment factor for small tanks with D < 30 feet

= 0.0771 (D) - 0.0013 (D2) - 0.1334; otherwise C = 1 for D > 30.Kc = product factor; for crude oil, Kc = 0.65. For all other organic liquids, Kc = 1.0.

V = tank capacity, gallons

N = number of turnovers per year == Annual throughput (gal) divided by tank capacity, VKN = turnover factor; for N > 36, KN = (180 + N)/6N. For N < 36, KN = 1

43.a.i. Annual emission from FIXTANK is the sum of emissions from individual fixed roofstorage tanks:

EFIXTANK, ANNUAL = ZLnxTANK/2000 (tons/year)

43 .b. Except as provided in Condition 43.f, VOC emissions from each internal floating roof storage tankgrouped under the emissions unit INTANK shall be calculated based on the following algorithms:


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(2) LINTANK = LR + LWD + Lp + LD (Ibs/yr)

LR = rim seal loss = Ks v" P* D Mv Kc

LWD = withdrawal loss ={0.943)^_CF_WL [1D

+ (Nc Fc)/D]

LF

LD

= deck

= deck

fitting

seam

; loss

loss

= FF

= KD

p*

SD

Mv

D2

Kc

P* Mv Kc

where: Ks = seal factor for average of tight fit, see TABLE-4, Attachment 2

v = average wind speed at the tank site; may use the nearest local weather station data; or

default = 7 mph (3 meter/sec.; reference -1993 DEQ Annual Report, pg. 7)(for INTANK, n = 0; v" = 1: wind does not affect INTANK)

n = seal-related wind speed exponent, see TABLE-4, Attachment 2

Kc = product factor; for crude oil, Kc = 0.4. For all other organic liquids, Kc = 1.0.

Q = annual throughput, bbl/yrCF = shell clingage factor, bbl/1000 ft2, see TABLE-5, Attachment 2WL = liquid density, Ibs/galP, PA , D, My, etc. are as defined for equation (1) of this condition.

P* = vapor pressure function = (-P/PA

[l+[l-(P/PA)]a5]0.5 12

FF = total deck fitting loss factor = [(NFI Kpi) + CNF2 Kp2) + ...... + (Npn Kpn)]

Npi = number of deck fittings of a particular type, see Tables 3 and 9, Attachment 2Kp; = deck fitting loss factor for a particular type, see TABLE 9, Attachment 2n = total number of different types of fittings

Nc = number of columns, dimensionless. For internal floatmg roof tank with column-

supported fixed roof, Nc = use tank-specific information, or see TABLE-3,

Attachment 2

Fc = effective column diameter, feet (column perimeter/n). For mternal floatmg roof tankwith column-supported fixed roof, use tank-specific effective column diameter, or

Fc = 1.1 for 9-inch by 7-inch built-up columns; 0.7 fir 8-inch-diameter pipe

columns, and 1.0 if column construction details are not known.

KD = deck seam loss per unit seam length factor = 0 for welded deck; 0.34 for bolted deckSD = deck seam length factor = total length of desk seams divided by the area of the deck;

if not known, refer to TABLE 10, Attachment 2P, PA , D, My, Kc, etc. are as defined for equation (2) of this condition

43.b.i. Annual emission from INTANK is the sum of emissions from individual internalfloating roof storage tanks:


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ElNTANK, ANNUAL = Z, LlNTANK / 2000 (tons/year)

43.c. The VOC emissions from marine loading operations, including the lightering operations, groupedunder the emissions unit MLOAD shall be calculated based on the following algorithms:

(3) LMLOAD = (l-eff)Q EF (Ibs/unit time)

43.C.L Annual emission from MLOAD is calculated by substituting annual throughput, Q(103 gal), in equation (3):

EMLOAD, ANNUAL = LMLOAD/IOOO (tons/year)

GasolineJet Kerosene

Dist. Oil No.2Res. Oil No.6

NaphthaVGOEthanol

EF(lbs/103gal)

Tank Ship &Ocean barges Barges

2.6 | 3.9

0.013

0.0129 x 10-5

3.8755.5 xl0-3

0.342

43.c.ii. Use the VOC control efficiency (i.e., % reduction) determined from source testingperformed per Condition 23.a; or

43.c.iii. Use the minimum control efficiency provided by the manufacturer until the sourcetest results are available; and

43.c.iv. Set VOC control efficiency to Zero when VCU is not utilized.

43.d. The VOC emissions from tanker truck/trailer loading operations grouped under the emissions unitTRACK shall be calculated by using the equation (4) below, and the efficiency (eff.) determinedfrom the source test:

(4) LTRACK = (l-eff./100)Q DL (Ibs/unit time)

DL = displacement loss = 12.46 (S P MW)/T (lbs/103 gal)

where: Q = throughput in "xl 000" gallonS = saturation factor, see TABLE-11, Attachment 2

P = true vapor pressure of liquid loaded, psia (see equation "P" below, only ifconversion ofReid vapor pressure (PRV?) to true vapor pressure (P) is needed)

MW= molecular weight of vapors. For gasoline (mixture) with known Ppvp;MWGAS = 72.833 - 1.3183(PRvp) + 0.15079(PRvp)2 - 0.0087302(PRvp)3

T = stock temperature, °R (= °F + 459.6)

P = exp[ (0.7553-413/T)SD1/2 log (PRVP) - (1.854 - 1042/T)SD1/2 +


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(2416/T-2.013) log (PRVP) - (8742/T) + 15.64]

where: PRVP = Reid vapor pressure, psia

SD = slope of American Society for Testing and Materials distillationcurve at 10% evaporated. For gasoline, SD = 3

eff. = the over-all control efficiency (%) of the vapor recoveiy unit (VRU), asdetermined fi-om source testing.

43.d.i. Annual emission from TRACK is calculated by substituting annual throughput, Q, inequation (4):

ETRACK, ANNUAL = LTRACK/2000 (tons/year)

43.cl.ii. Annual fugitive emission from TRACK is calculated by substituting annualthroughput, Q, in the equation below:

ETRACK, ANNUAL FUGITIVE = 10.79 X 10-2 Q / 2000 (tons/year)

43.e. VOC emissions from auxiliary material handling equipment grouped under the emissions unitPIPE shall be calculated using the equation (8), based on emission factors (EFi) provided m theEPA publication (EPA-453/R-95-017); "Protocol for Equipment Leak Emission Estimate."

(8) LpipE = E[Ni EF,] (Ibs/hr)

where: N; = number of component "i"

EF; = EPA emission factor for component "i", Ibsyoc/hr

Component ("i") Type

Connectors

Valves

Loading Ann Valves

Open Ended Lines

Pumps (seals)Other

Average Emission Factor, EF; (Ibs/hr)Gas Light Liquid

6.7 x 10-5

1.6xl0-4

4.5 x 10-2

6.7 x 10-3

1.4 xl0-3

2.3 x 10-5

1.5 x 10-4

8.7 x 10-4

6.5 xl0-3

9.3 x 10-4

2.5 xl0-4

43.e.i. Annual emission from PIPE is calculated as follow:

EPIPE, ANNUAL = (8760/2000) LPIPE (tons/year)

43.e.ii. The permittee must update the number of component "i" at the time of permit renewal

or major modification, whichever is sooner.

43.f. For storage tank emissions from FIXTANK and FNTANK, the permittee may use the EPA Tanksoftware to calculate the VOC emissions.

EMISSION FEES

44. The permittee must base emission fees on the Plant Site Emissions Limits, unless permittee elects to reportactual emissions for one or more permitted processes/pollutants. [OAR 340-220-0090]


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GENERAL TESTING REQUIREMENTS [OAR 340-218-0050(1)]

45. Unless otherwise specified in this permit, all testing must be conducted in accordance with theDepartment's Source Sampling Manual. [OAR 340-212-0120]

45.a. Unless otherwise specified by a state or federal regulation, the permittee must submit a source test

plan to the Department at least 30 days prior to the date of the test. The test plan must be preparedin accordance with the Source Sampling Manual and address any planned variations oralternatives to prescribed test methods. The permittee should be aware that if significantvariations are requested, it may require more than 30 days for the Department to grant approvaland may require EPA approval in addition to approval by the Department.

45.b. Only regular operating staff may adjust the processes or emission control device parametersduring a compliance source test and within two (2) hours prior to the tests. Any operatingadjustments made during a compliance source test, which are a result of consultation during thetests with source testing personnel, equipment vendors, or consultants, may render the source test

invalid.

45.c. Unless otherwise specified by permit condition or Department approved source test plan, allcompliance source tests must be performed as follows:

45.C.L at least 90% of the design capacity for new or modified equipment;45.C.U. at least 90% of the maximum operating rate for existing equipment; or45.c.iii. at 90 to 1 10% of the normal maximum operating rate for existmg equipment. For

purposes of this permit, the normal maximum operating rate is defined as the 90thpercentile of the average hourly operating rates during a 12 month period immediatelypreceding the source test. Data supportmg the normal maximum operating rate must

be included with the source test report.

45.d. Each source test must consist of at least three (3) test mns and the emissions results must bereported as the arithmetic average of all valid test mns. If for reasons beyond the control of thepermittee a test run is invalid, the Department may accept two (2) test runs for demonstratingcompliance with the emission limit or standard.

45.e. Source test reports prepared in accordance with the Department's Source Sampling Manual must

be submitted to the Department within 45 days of completing any required source test, unless adifferent time period is approved in the source test plan submitted prior to the source test.


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GENERAL MONITORING AND RECORDKEEPING REQUIREMENTS [OAR 340-218-0050(3)(b)]

General Monitoring Requirements:

46. The permittee must not knowingly render inaccurate any required monitoring device or method. [OAR340-218-0050(3)(a)(E)]

47. Methods used to determine actual emissions for fee purposes must also be used for compliance

determination and can be no less rigorous than the requu-ements of OAR 340-218-0080. [OAR 340-218-

0050(3)(a)(F)]

48. Monitoring requirements must commence on the date of permit issuance unless otherwise specified m the

permit or an applicable requirement. [OAR 340-218-0050(3)(a)(G)]

General Recordkeeping Requirements

49. The permittee must maintain the following general records attesting and monitoring required by thispermit: [OAR 340-218-0050(3)(b)(A)]

49.a. the date, place as defined in the permit, and time of sampling or measurements;

49.b. the date(s) analyses were performed;49.c. the company or entity that performed the analyses;49.d. the analytical techniques or methods used;49.e. the results of such analyses;

49.f. the operating conditions as existing at the time of sampling or measurement; and49.g. the records of quality assurance for continuous monitoring systems (including but not limited to

quality control activities, audits, calibration drift checks).

50. Unless otherwise specified by permit condition, the pennittee must make every effort to maintain 100percent of the records required by the permit. If information is not obtained or recorded for legitimatereasons (e.g., the monitor or data acquisition system malfunctions due to a power outage), the missing

record(s) will not be considered a permit deviation provided the amount of data lost does not exceed 10%of the averaging periods in a reportmg period or 10% of the total operating hours in a reporting period, if noaveraging time is specified. Upon discovering that a required record is missing, the permittee mustdocument the reason for the missing record. In addition, any missing record that can be recovered from

other available information will not be considered a missing record. [OAR 340-214-0110, 340-212-0160,and 340-218-0050(3)(b)]

51. Recordkeeping requirements must commence on the date of permit issuance unless otherwise specified in

the permit or an applicable requirement. [OAR 340-218-0050(3)(b)(C)]

52. Unless otherwise specified, the permittee must retain records of all requu'ed monitoring data and supportinformation for a period of at least five (5) years from the date of the monitormg sample, measurement,report, or application. Support information includes all calibration and maintenance records and all originalstrip-chart recordings (or other original data) for continuous monitoring instrumentation, and copies of allreports required by the permit. All existing records required by the previous Air Contaminant DischargePermit or Oregon Title V Operating Permit must also be retained for five (5) years from the date of themonitoring sample, measurement, report, or application. [OAR 340-218-0050(b)(B)]


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REPORTING REQUIREMENTS [OAR 340-218-0050(3)(c)]

GENERAL REPORTING REQUIREMENTS

53. Excess Emissions Reporting: The permittee must report all excess emissions as follows: [OAR 340-214-0300 through 340-214-0360]

53 .a. Immediately (no later than the next working day) notify the Department of an excess emissionevent by phone, e-mail, or facsimile; and

53.b. Within 15 days of the excess emissions event, submit a written report that contains the followinginformation: [OAR 340-214-0340(1)]

53.b.i. The date and time of the beginning of the excess emissions event and the duration orbest estimate of the time until return to normal operation;

53.b.ii. The date and time the owner or operator notified the Department of the event;53.b.iii. The equipment involved;53.b.iv. Whether the event occurred during planned startup, planned shutdown, scheduled

maintenance, or as a result of a breakdown, malfunction, or emergency;

53.b.v. Steps taken to mitigate emissions and corrective action taken, mcluding whether the

approved procedures for a planned startup, shutdown, or maintenance activity were

followed;53.b.vi. The magnitude and duration of each occurrence of excess emissions during the course

of an event and the increase over normal rates or concentrations as determined by

contmuous monitoring or best estimate (supported by operating data andcalculations);

53.b.vii. The fmal resolution of the cause of the excess emissions; and

53.b.viii. Where applicable, evidence supportmg any claim that emissions in excess oftechnology-based limits were due to any emergency pursuant to OAR 340-214-0360.

53 .c. In the event of any excess emissions which are of a nature that could endanger public health andoccur during non-business hours, weekends, or holidays, the pennittee must immediately notify

the Department by calling the Oregon Accident Response System (OARs). The current number is1-800-452-0311.

53.d. If startups, shutdowns, or scheduled maintenance may result in excess emissions, the permittee

must submit startup, shutdown, or scheduled maintenance procedures used to minimize excess

emissions to the Department for prior authorization, as required in OAR 340-214-0310 and 340-214-0320. New or modified procedures must be received by the Department in writing at least 72hours prior to the first occuiTence of the excess emission event. The permittee must abide by theapproved procedures and have a copy available at all times.

53.e. The permittee must notify the Department of planned startup/shutdown or scheduled maintenanceevents.

5 3.f. The permittee must continue to maintain a log of all excess emissions in accordance with OAR340-214-0340(3). However, the permittee is not required to submit the detailed log with the semi-annual and annual monitoring reports. The permittee is only required to submit a brief summarylisting the date, time, and the affected emissions units for each excess emission that occurredduring the reporting period. [OAR 340-218-0050(3)(c)]


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54. Permit Deviation Reporting. The permittee must promptly report deviations from permit requirements thatdo not cause excess emissions, including those attributable to upset conditions, as defined in the permit, theprobable cause of such deviations, and any corrective actions or preventive measures taken. "Prompt"

means within 15 days of the deviation. Deviations that cause excess emissions, as specified in OAR 340-214-0300 through 340-214-0360 must be reported in accordance with Condition 53.

55. All required reports must be certified by a responsible official consistent with OAR 340-218-0040(5); [OAR340-218-0050(3)(c)(D)]

56. Reporting requirements must commence on the date of permit issuance unless otherwise specified in thepermit. [OAR 340-218-0050(3)(c)(E)]

Addresses of regulatory agencies are the following, unless otherwise instructed:

Submit all Notices andapplications that do not includepayment to the NWR AQ PermitCoordinator.

Submit all reports (annual reports,source test plans and reports, etc.)

to DEQ. If you know the name ofthe Air Quality staff memberresponsible for your permit, pleaseinclude it.

DEQ NWR Air Quality700 NE Multnomah St. Ste. 600Portland OR 97232503-229-5263

Submit payments for invoices,applications to modify the permit,and any other payments to DEQ'sBusiness Office:

DEQ Accounting700 NE Multnomah St, Suite 600Portland, OR 97232503-229-5359

Submit all reports for EPArequirements to:

USEPARegion 10 (20-C04)1200 Sixth Avenue, Suite 155Seattle, WA 98101

Semi-Annual and Annual Reports

57. The permittee must submit two (2) paper copies and one (1) electronic copy of reports of any reqwredmonitoring at least every 6 months, completed on forms approved by DEQ. Six month periods are January1 to June 30, and July 1 to December 3 1. If the report due date falls on a weekend or Monday holiday, thepermittee must submit their report on the next business day. One paper copy of the report must besubmitted to the EPA and two copies (one paper copy and one electronic copy) to the DEQ regional office.All instances of deviations from permit requirements must be clearly identified m such reports: [OAR 340-218-0050(3)(c)(A) and 340-218-0080(6)(d)]

57.a. The first semi-annual report is be due on July 31 and must include the semi-armual compliance

certification, OAR 340-218-0080.

57.b. The annual report is due on February 15 and must consist of the following:

57.b.i. the emission fee report; [OAR 340-220-0100]57-b.ii. the NOx and VOC emission statement, if applicable; [OAR 340-214-0220];57.b.iii. a summary of the excess emissions upset log; [OAR 340-214-0340]57.b.iv. the second semi-annual compliance certification; [OAR 340-218-0080]57.b.v. the annual certification that the risk management plan is being properly implemented;

OAR 340-244-0230; [OAR 340-218-0080(7)]57.b.vi. Greenhouse gases emissions in accordance with OAR 340 Division 215; [OAR 340-

215-0040(3)(a)] and


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57.b.vii. Other annual reporting requirements:

EMISSIONS UNITFIXTANK

INTANK

MLOAD

TRACK

PIPESBOILER

ANNUAL PARAMETERSVOC emissionsProducts throughput

VOC emissionsProducts throughput

VOC emissionsProducts throughputs

VOC emissionsProducts throughputs

VOC emissions

PM2.5, PMio, S02, NOx, CO, & VOCemissions, NG and/or Distillate oil usage

UNITtons/yrgallons/yr

tons/yrgallons/yr

tons/yrgallons/yr

tons/yrgallons/yr

tons/yr

tons/yr106ft3/yr,ga^

57.c.

57.b.viii. "End of the month summary" of annual VOC emissions from each of the emissions

units FIXTANK, INTANK, MLOAD, TRACK, and the annual products throughputsassociated with each emissions unit identified;

57.b.ix. annual VOC emissions from PIPES;57.b.x. "End of the month summary" of annual emissions of criteria pollutants from

BOILEFR and associated fuel usage.

The Notification of Compliance Status Report [as specified in Condition 38.a] and the ExcessEmissions Report [as specified in Condition 38.c], if applicable, shall be submitted at the sametime as the semi-annual compliance certification submitted per Conditions 57.a and 57-b.iv above.

58. The semi-annual compliance certification must include the following (provided that the identification ofapplicable information may cross-reference the permit or previous reports, as applicable): [OAR 340-218-

0080(6)(c)]

5 8. a. The identification of each term or condition of the permit that is the basis of the certification;

58.b. The identification of the method(s) or other means used by the owner or operator for determiningthe compliance status with each term and condition during the certification period, and whethersuch methods or other means provide continuous or intermittent data. Such methods and othermeans must mclude, at a minimum, the methods and means required under OAR 340-218-

0050(3).

Note: Certification of compliance with the monitormg conditions in the permit is sufficient tomeet this requirement, except when the permittee must certify compliance with new applicableconditions that are not yet in the permit. When certifying compliance with new applicableconditions that are not yet in the permit, the permittee must provide the mformation requu-ed bythis condition. If necessary, the owner or operator also must identify any other materialinformation that must be included in the certification to comply with section 113(c)(2) of theFCAA, which prohibits knowingly makmg a false certification or omitting material information;

58.c. The status of compliance with terms and conditions of the permit for the period covered by thecertification, based on the method or means designated in Condition 5 8.b. The certification mustidentify each deviation and take it into account in the compliance certification. The certificationmust also identify as possible exceptions to compliance any periods during which compliance isrequu-ed and in which an excursion or exceedance, as defined under OAR 340-200-0020,

occurred; and

58.d. Such other facts as the Department may require to determine the compliance status of the source.


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58.e. NSPS REPORTING REQUIREMENT The permittee must submit semi-annual reports toDEQ by reporting dates specified in Conditions 57.a and 57.b. The report must include thefollowing information: [40 CFR 60.48c (j)]

58.e.i. Calendar dates covered in the reporting period;

58.e.ii. type of fuel combusted during the reporting period;58.e.iii. 30-day average sulfur content, calculated during the reporting period that ends with

the last 30-day period in the quarter (applicable only if oil is combusted);58.e.iv. If fuel supplier certification is used to demonstrate compliance, include in the report

the information obtained per Condition 21.c and a certified statement by theresponsible officer that the records of fuel supplier certifications submitted representall of the fuel combusted during the quarter (applicable only if oil is combusted).

59. Notwithstanding any other provision contained in any applicable requirement, the owner or operator mayuse monitoring as required under OAR 340-218-0050(3) and incorporated into the permit, in addition toany specified compliance methods, for the purpose of submitting compliance certifications. [OAR 340-218-0080(6)(e)]

ADDITIONAL REPORTS

60. Greenhouse Gas Registration and Reporting: If the calendar year emission rate of greenhouse gases(C02e) is greater than or equal to 2,756 tons (2,500 metric tons), the permittee must register and report itsgreenhouse gas emissions with DEQ in accordance with OAR 340-215. The greenhouse gas report must becertified by the responsible official consistent with OAR 340-218-0040(5).

61. The permittee must submit the following additional reports and/or information to the DEQ - NorthwestRegion as required by specific conditions within the permit:

61 .a. Monthly RVP-report during the control period, as specified m Condition 10;61 .b. source test plans/notifications prior to conducting actual test/measurements;

61 .c. source test results within 45 days after the source test was done; and

61 .d. when requested by the Department, submit all relevant records, data, and support information

maintained at the plant site per monitoring and recordkeeping requirements of this permit.

NON-APPLICABLE REQUIREMENTS

62. Divisions of Chapter 340, Air Quality Oregon Administrative Rules (OARs), currently determined notapplicable to the permittee are listed below. [OAR 340-218-0110]

62.a. The following OARs are not applicable because the source is not in the source category cited inthe rules:

DivisionDivisionDivisionDivisionDivisionDivisionDivisionDivisionDivisionDivisionDivision

202216218224230232234236238244248

AllAll0090,0100AllAll0130,0140, 0160,0170 through 0240AllAll01000200All


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Division 256 AllDivision 260 All

62.b. The following OARs are not applicable because the source is outside the special control area, non-

attainment area or county cited in the rules:

Division 210 0210,0220Division 222 0042Division 240 AllDivision 264 0100,0120,0140,0150,0160,0170

62.c. The following OARs are not applicable because the source does not have specific emissions unitscited in the rules:

Division 212 0200 through 0280Division 226 0310Division 228 0300Division 264 0190

62. d. The following OARs are not applicable because the source does not sell, distribute, use, or make

available for use, the fuel type cited m the mles:

Division 228 0100, 0120, 0130

62.e. The following OARs are not applicable because no apparent changes have been made or themethod/procedure is not used by the facility:

Division 224 0050 through 0100Division 226 0400Division 244 0110,0120,0130,0140,0180Division 268 0030

63. The following federal regulations are not applicable to the permittee at the time of permit issuance becausethe source is not in the source category cited in the rules:

40 CFR Part 55, 57, 68,72,73,75,76,40 CFR Part 60 (except subparts A, K, Ka, Kb, and the Appendices),40 CFR Part 61 (except subparts A and M and the Appendices),40 CFR Part 63 (except subparts 6B, A, M, and the Appendices),40 CFR Part 82 (except subpart F),40 CFR Parts 85 through 89,Section 129 of the FCAA, Solid Waste,Section 183(e) of the FCAA, Consumer and commercial products,Section 183(f) of the FCAA, Tank Vessels.

Issued . Permit Number: 26-2029-TV-01Expiration Date: 04/01/2023

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GENERAL CONDITIONS

Gl. General Provision

Terms not otherwise defined in this permit have the meaning assigned to such terms in the referencedregulation.

G2. Reference materials

Where referenced in this permit, the versions of the following materials are effective as of the dates notedunless otherwise specified in this permit:

a. Source Sampling Manual; January 23, 1992 - State Implementation Plan Volume 3, Appendix A4;b. Continuous Monitoring Manual; January 23, 1992 - State Implementation Plan Volume 3,

Appendix A6; andc. All state and federal regulations as in effect on the date of issuance of this permit.

G3. Applicable Requirements FOAR 340-218-0010(3)(b)1

Oregon Title V Operating Permits do not replace requirements in Air Contaminant Discharge Permits(ACDP) issued to the source even if the ACDP(s) have expked. For a source operating under a Title Vpermit, requirements established in an earlier ACDP remain in effect notwithstanding expiration of theACDP or Title V permit, unless a provision expires by its terms or unless a provision is modified orterminated following the procedures used to establish the requirement initially. Source specificrequirements, including, but not limited to TACT, RACT, BACT, and LAER requirements, established inan ACDP must be incorporated into the Oregon Title V Operating Permit and any revisions to thoserequirements must follow the procedures used to establish the requirement initially.

G4. Compliance [OAR 340-218-0040(3)(n)(C), 340-218-0050(6), and 340-218-0080(4)]

a. The permittee must comply with all conditions of this permit. Any permit conditionnoncompliance constitutes a violation of the Federal Clean Air Act and/or state rules and isgrounds for enforcement action; for permit termination, revocation and re-issuance, or

modification; or for denial of a permit renewal application. Any noncompliance with a permitcondition specifically designated as enforceable only by the state constitutes a violation of staterules only and is grounds for enforcement action; for permit termination, revocation and re-

issuance, or modification; or for denial of a permit renewal application.

b. Any schedule of compliance for applicable requirements with which the source is not incompliance at the time of permit issuance is supplemental to, and does not sanction

noncompliance with the applicable requirements on which it is based.c. For applicable requirements that will become effective during the permit term, the source must

meet such requirements on a timely basis unless a more detailed schedule is expressly required bythe applicable requirement.

G5. Masking Emissions:

The permittee must not install or use any device or other means designed to mask the emission of an aircontaminant that causes or is likely to cause detriment to health, safety, or welfare of any person orotherwise violate any other regulation or requirement. [OAR 340-208-0400] This condition is enforceableonly by the State.

G6. Credible Evidence:


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Notwithstanding any other provisions contained in any applicable requirement, any credible evidence maybe used for the purpose of establishing whether a person has violated or is in violation of any suchapplicable requirements. [OAR 340-214-0120]

G7. Certification [OAR 340-214-0110, 340-218-0040(5), 340-218-0050(3)(c)(D), and 340-218-0080(2)]

Any document submitted to the Department or EPA pursuant to this permit must contain certification by aresponsible official of truth, accuracy and completeness. All certifications must state that based oninformation and belief formed after reasonable inquiry, the statements and information in the document aretrue, accurate, and, complete. The permittee must promptly, upon discovery, report to the Department a

material error or omission in these records, reports, plans, or other documents.

G8. Open Burning [OAR Chapter 340, Division 264]

The permittee is prohibited from conducting open burning, except as may be allowed by OAR 340-264-0020 through 340-264-0200.

G9. Asbestos [40 CFR Part 61, Subpart M (federally enforceable), OAR Chapter 340-248-0005 through 340-248-0180 (state-only enforceable) and 340-248-0205 through 340-248-0280]

The permittee must comply with OAR Chapter 340, Division 248, and 40 CFR Part 61, Subpart M whenconducting any renovation or demolition activities at the facility.

G 10. Stratospheric Ozone and Climate Protection [40 CFR 82 Subpart F, OAR 340-260-0040]

The permittee must comply with the standards for recycling and emissions reduction pursuant to 40 CFRPart 82, Subpart F, Recycling and Emissions Reduction.

Gil. Permit Shield [OAR 340-218-0110]

a. Compliance with the conditions of the permit is deemed compliance with any applicablerequirements as of the date of permit issuance provided that:

i. such applicable requirements are included and are specifically identified in the permit, orii. the Department, in acting on the permit application or revision, determines in writing that

other requirements specifically identified are not applicable to the source, and the permitincludes the determination or a concise summary thereof.

b. Nothing in this rule or in any federal operating permit alters or affects the following:

i. the provisions ofORS 468.115 (enforcement in cases of emergency) and ORS 468.035(function of department);

ii. the liability of an owner or operator of a source for any violation of applicablerequirements prior to or at the time of permit issuance;

iii. the applicable requirements of the national acid rain program, consistent with section408(a) of the FCAA; or

iv. the ability of the Department to obtain information from a source pursuant to ORS468.095 (investigatory authority, entry on premises, status of records).

c. Sources are not shielded from applicable requirements that are enacted durmg the permit term,unless such applicable requirements are incorporated into the permit by administrativeamendment, as provided in OAR 340-218-0150(l)(h), significant permit modification, orreopening for cause by the Department.

G12. Inspection and Entry [OAR 340-218-0080(3)]


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Upon presentation of credentials and other documents as may be required by law, the permittee must allowthe Department of Environmental Quality, or an authorized representative (including an authorizedcontractor acting as a representative of the EPA Administrator), to perform the following:

a. enter upon the permittee's premises where an Oregon Title V Operating Permit program source is

located or emissions-related activity is conducted, or where records must be kept under the

conditions of the permit;b. have access to and copy, at reasonable times, any records that must be kept under conditions of the

permit;c. mspect,'at reasonable times, any facilities, equipment (including monitoring and air pollution

control equipment), practices, or operations regulated or required under the permit; andd. as authorized by the FCAA or state rules, sample or monitor, at reasonable times, substances or

parameters, for the purposes of assuring compliance with the permit or applicable requirements.

G13. Fee Payment [OAR 340-220-0010, and 340-220-0030 through 340-220-0190]

The permittee must pay an annual base fee and an annual emission fee for particulates, sulfur dioxide,nitrogen oxides, and volatile organic compounds. The permittee must submit payment to the Departmentof Environmental Quality, Busmess Office, 811 SW 6th Avenue, Portland, OR 97204, within 30 days ofthe date the Department mails the fee invoice or August 1 of the year followmg the calendar year for whichemission fees are paid, whichever is later. Disputes must be submitted in writing to the Department ofEnvu-onmental Quality. Payment must be made regardless of the dispute. User-based fees will be chargedfor specific activities (e.g., computer modeling review, ambient monitoring review, etc.) requested by thepermittee.

G14. Off-Permit Changes to the Source [OAR 340-218-0140(2)]

a. The permittee must monitor for, and record, any off-permit change to the source that:

i. is not addressed or prohibited by the permit;ii. is not a Title I modification;iii. is not subject to any requirements under Title IV of the FCAA;iv. meets all applicable requu-ements;

v. does not violate any existing permit term or condition; andvi. may result in emissions of regulated air pollutants subject to an applicable requirement

but not otherwise regulated under this permit or may result in insignificant changes asdefined in OAR 340-200-0020.

b. A contemporaneous notification, if required under OAR 340-218-0140(2)(b), must be submitted tothe Department and the EPA.

c. The permittee must keep a record describing off-permit changes made at the facility that result inemissions of a regulated air pollutant subject to an applicable requirement, but not otherwiseregulated under the permit, and the emissions resulting from those off-permit changes.

d. The permit shield of condition G9 does not extend to off-permit changes.

G 15. Section 502fb)d0) Changes to the Source [OAR 340-218-0140(3)]

a. The permittee must monitor for, and record, any section 502(b)(10) change to the source, which isdefined as a change that would contravene an express permit term but would not:

i. violate an applicable requirement;ii. contravene a federally enforceable permit term or condition that is a monitoring,

recordkeeping, reporting, or compliance certification requirement; or


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iii. be a Title I modification.

b. A minimum 7-day advance notification must be submitted to the Department and the EPA inaccordance with OAR 340-218-0140(3)(b).

c. The permit shield of condition G9 does not extend to section 502(b)(10) changes.

G 16. Administrative Amendment [OAR 340-2 18-0150]

Administrative amendments to this permit must be requested and granted in accordance with OAR 340-218-0150. The permittee must promptly submit an application for the following types of administrativeamendments upon becoming aware of the need for one, but no later than 60 days of such event:

a. legal change of the registered name of the company with the Corporations Division of the State ofOregon, or

b. sale or exchange of the activity or facility.

G17. Minor Permit Modification [OAR 340-218-0170]

The permittee must submit an application for a minor permit modification in accordance with OAR 340-218-0170.

G18. Significant Permit Modification [OAR 340-218-0180]

The permittee must submit an application for a significant permit modification in accordance with OAR340-218-0180

G 19. Staying Permit Conditions [OAR 340-218-0050(6)(c)]

Notwithstanding Conditions G 16 and G 17, the filing of a request by the permittee for a permitmodification, revocation and re-issuance, or termination, or of a notification of planned changes or

anticipated noncompliance does not stay any permit condition.

G20. Construction/Operation Modification [OAR 340-2 18-0190]

The permittee must obtain approval from the Department prior to construction or modification of anystationary source or air pollution control equipment in accordance with OAR 340-210-0200 through OAR340-210-0250.

G21. New Source Review Modification [OAR 340-224-0010]

The permittee may not begin construction of a major source or a major modification of any stationarysource without having received an au- contaminant discharge permit (ACDP) from the Department andhaving satisfied the requirements of OAR 340, Division 224.

G22. Need to Halt or Reduce Activity Not a Defense [OAR 340-218-0050(6)(b)]

The need to halt or reduce activity will not be a defense. It will not be a defense for a permittee in anenforcement action that it would have been necessary to halt or reduce the permitted activity in order tomaintain compliance with the conditions of this permit.

G23. Duty to Provide Information [OAR 340-218-0050(6)(e) and OAR 340-214-01 10]

The permittee must furnish to the Department, within a reasonable time, any information that theDepartment may request in writing to determine whether cause exists for modifying, revoking and


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reissuing, or terminating the permit, or to determine compliance with the permit. Upon request, the

permittee must also furnish to the Department copies of records required to be retained by the permit or, forinformation claimed to be confidential, the permittee may furnish such records to the Department alongwith a claim of confidentiality.

G24. Reopenme for Cause [OAR 340-218-0050(6)(c) and 340-218-0200]

a. The permit may be modified, revoked, reopened and reissued, or terminated for cause as

determined by the Department.b. A permit must be reopened and revised under any of the circumstances listed in OAR 340-218-

0200(1 )(a).c. Proceedings to reopen and reissue a permit must follow the same procedures as apply to initial

permit issuance and affect only those parts of the permit for which cause to reopen exists.

G25. Severabilitv Clause [OAR 340-218-0050(5)]

Upon any administrative or judicial challenge, all the emission limits, specific and general conditions,monitoring, recordkeeping, and reporting requirements of this permit, except those being challenged,remain valid and must be complied with.

G26. Permit Renewal and Expiration [OAR 340-218-0040(l)(a)(D) and 340-218-0130]

a. This permit expires at the end of its term, unless a timely and complete renewal application issubmitted as described below. Permit expiration terminates the permittee's right to operate.

b. Applications for renewal must be submitted at least 12 months before the expiration of this permit,unless the Department requests an earlier submittal. If more than 12 months is required to processa permit renewal application, the Department must provide no less than six (6) months for theowner or operator to prepare an application.

c. Provided the permittee submits a timely and complete renewal application, this permit will remainin effect until final action has been taken on the renewal application to issue or deny the permit.

G27. Permit Transference [OAR340-218-0150(l)(d)]

The permit is not transferable to any person except as provided in OAR 340-218-0150(l)(d).

G28. Property Rights [OAR 340-200-0020 and 340-218-0050(6)(d)]

The permit does not convey any property rights in either real or personal property, or any exclusiveprivileges, nor does it authorize any injury to private property or any invasion of personal rights, nor anyinfringement of federal, state, or local laws or regulations, except as provided in OAR 340-218-0110.

G29. Permit Availability [OAR 340-200-0020 and 340-218-0120(2)]

The permittee must have available at the facility at all times a copy of the Oregon Title V Operating Permitand must provide a copy of the permit to the Department or an authorized representative upon request.

ALL INQUIRIES SHOULD BE DIRECTED TO:Northwest Region

700 N.E. Multnomah St., #600Portland, OR 97232 Telephone: (503) 229-5263


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ATTACHMENT 1

I. Test Methods and Compliance Procedures

The methods and procedures outlined in this Attachment-1 are for determining compliance with the massemission limitations (e.g., 80 mg/L , 35 mg/L, or 10 mg/L) applicable to TRACK, or the alternative controlrequirements (e.g., 95% VOC reduction) applicable to the storage tanks as identified in the permit:

1. Immediately prior to a performance test required to determine compliance with the mass emissionlimitation of 80 mg/L specified in Condition 24.a.i, all potential sources of vapor and liquid leakage fromthe terminal's vapor collection system equipment must be monitored for leaks accordmg to the procedures

outlined in Section II. of this Attachment 1. The monitoring must be conducted only while a gasoline tanktruck is being loaded; and all leaks must be repau-ed prior to conducting the performance test.

A reading of 500 parts per million by volume (ppmv) or greater as methane shall be considered a leak, forthe purpose of determining compliance with the VOC limits specified in Condition 24.a.i.

2. The test procedure is as follows:

2.a. All testing equipment shall be prepared and installed as specified in the appropriate test methods.

2.b. The time period for a performance test shall be not less than 6 hours, during which at least300,000 L (80,000 gal) of gasoline are loaded. If the throughput criterion is not met during theinitial 6 hours, the test shall either continue until the throughput criterion is met, or resumed thenext day with another complete 6 hours of testing. As much as possible, testing should beconducted during the 6-hour period m which the highest throughput normally occurs.

2.c. For intermittent vapor control systems:

2.c.i. The vapor holder level shall be recorded at the start of the performance test. The endof the perfonnance test shall coincide with a time when the vapor holder is at itsoriginal level.

2.c.ii. At least two startups and shutdowns of the vapor processor shall occur during theperformance test. If this does not occur under automatically controlled operation, thesystem shall be manually controlled.

2.d. An emission testing interval shall consist of each 5-minute period during the performance test.For each interval:

2.d.i. The readmg from each measurement instrument shall be recorded.

2.d.ii. The volume exhausted (Ves) and the average total organic compounds concentration

(Ce) in the exhaust vent shall be determined, as specified in the appropriate testmethod. The average total organic compounds concentration shall correspond to thevolume measurement by taking into account the sampling system response time.

2.e. The mass emitted during each testing interval shall be calculated as follows:

Mei = 10-6KVesCe


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where: Mgj = Mass of total organic compounds (milligrams [mg]) emitted during testing interval i.

Vgg = Volume ofair-vapor mixture exhausted (cubic meters [m-^]), at standard conditions.

Cg = Total organic compounds concentration (measured as carbon) at the exhaust vent (ppmv).

K = Density ofcalibration gas (milligrams/cubic meter [mg/m-^]) at standard conditions

(1.83xl06 forpropane; 2.41xl06 forbutane).

s = Standard conditions, 20°C and 760 millimeters of mercury (mm Hg).

2.f. The total organic compounds mass emissions shall be computed as follows:

,7

E = ^ Mei/L1=1

where: E = Mass of total organic compounds emitted per volume of gasoline loaded, mg/L.

L = Total volume of gasoline loaded, L.

n = Number of testing intervals.

2.g. In determining the volume (L) of gasoline dispensed during the performance test, terminal recordsor readings from gasoline dispensing meters at each loading rack shall be used.

2.h. In determinmg volume (Vgg ) at the exhaust vent:

2.h.i. Method 2B for combustion vapor control systems.

2.h.ii. Method 2A for all other vapor control systems.

2.i. In determming total organic compounds concentration (Ce) at the exhaust vent, at each interval,

Method 25A or 25B. The calibration gas shall be either propane or butane. The permittee mayadjust the emission results to exclude the methane and ethane content in the exhaust vent by anymethod (e.g.. Method 18) approved by the Department.

II. Leak Detection Methods for Volatile Organic Compounds

3. Permittee is required to carry out a leak detection monitoring program in accordance with the followingmethods and procedures:

3.a. Monitoring must be performed in accordance with Method 21 of 40 CFR Part 60, Appendix A.

3 .b. The detection instrument must meet the performance criteria of Method 21.

3.c. The detection instrument must be calibrated before and after use on each day of its use by themethods specified in Method 21. Failure to achieve a post-use calibration precision of less than10 percent shall constitute grounds for rejecting all tests performed since the last pre-usecalibration. In such cases, required leak tests must be re-performed.

3 .d. Calibration gases must be:

3.d.i. Zero air (less than 10 parts per million [ppm] of hydrocarbon in air).3.d.ii. A mixture ofhydrocarbon-gas (e.g., methane, propane) and air at a concentration of

approximately, but less than, 500 ppm hydrocarbon.

3.e. The detection instrument probe shall be traversed around all potential leak interfaces as close tothe interface as possible as described in Method 21.


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4. When equipment is tested for compliance with the requirement that there be no detectable emissions, thetest shall comply with the following:

4.a. The requirements outlined in the Section II Condition 3 of this attachment shall apply and shall bemet; and

4.b. The background level shall be determined as set forth in Method 21.

5. Guidance documents for Leak detection tests include the following:

5.a. "APTI Course SI 417-Controllmg Volatile Organic Compound Emissions from Leaking ProcessEquipment," EPA-45 0/2-82-015.

5.b. "Portable Instrument User's Manual for Monitoring VOC Sources," EPA-340/1-86-015.

5.c. "Protocols for Generatmg Unit-Specific Emission Estimates for Equipment Leaks ofVOC andHAP," EPA-450/3-88-010.

5.d. "Petroleum Refinery Enforcement Manual," EPA-340/1-80-008.

6. Use of adaptations to test methods

Use of an adaptation to any of the analytical methods specified in Conditions 3 through 4 of this attachment1 must be approved in writing by the Department on a case-by-case basis. The permittee must submitsufficient documentation for the Department to find that the analytical methods specified in Conditions 3through 4 of this attachment 1 will yield inaccurate results and that the proposed adaptation is appropriate.


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ATTACHMENT 2

TABLE-1. Paint Factors for

TANK

Roof

WhiteAluminum (specular)WhiteAluminum (specular)WhiteAluminum (diffuse)WhiteLight grayMedium gray

Fixed Roof Tanks

COLOR

ShellWhiteWhiteAluminum (specular)Aluminum (specular)Aluminum (diffuse)Aluminum (diffuse)GrayLight grayMedium gray

Good1.00

1.041.161.201.301.391.30

1.331.40

PAINT FACTOR (Fp)Paint Condition

Poor

1.15

1.181.241.291.381.461.381.44a

1.58a

° Estimated from the ratios of the seven preceding paint factors.

TABLE-2.

Tank colorWhiteAluminumGrayBlack

Average Annual Storage Temperature

as a Function of Tank Paint Color

Average AnnualStorage Temperature, Ts

TA + Oa

TA + 2.5

TA + 3.5

TA + 5.0

" TA is the average annual ambient temperature in °F.

NOTE: True vapor pressure for organic liquids are determined at the stored liquid temperature, Ts,

which may be calculated by knowing the color of the tank and the average ambient temperature, TA.

TABLE-3. Typical Number of Columns ( Nc) as a Function of Tank Diameter (D, in feet) for InternalFloating Roof Tanks with Column-Supported Fixed Roofs'

TankDiameterRange, D

(feet)

TypicalNumber ofColumns,

Nc

TankDiameter

Range, D

(feet)


Nc

TankDiameterRange, D(feet)


Nc0- 85

85 - 100100-120120- 135135- 150

16789

150-170170-190190-220220 - 235235 - 270

1619223137

270 - 275275 - 290290-330330-360360-400

4349617181

This table was derived from a survey of users and manufacturers. The actual number of columns in a particular tank may vary greatly

with age, fixed roof style, loading specifications, and manufacturing prerogative. Data in this table should not supersede information on

actual tanks


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TABLE-4. Rim Seal Loss Factors a

Tank Construction and Rim Seal System

Welded external floating Rim Seal System:1. Mechanical shoe seal

a. Primary only

b. Shoe-mounted secondary

c. Rim-mounted secondary

2. Liquid-mounted resilient filled seala. Primary only

b. Weather shieldc. Rim-mounted secondary

3. Vapor-mounted resilient filled seala. Primary onlyb. Weather shieldc. Rim-mounted secondary

Riveted external floating roof tanks:1. Mechanical shoe seal

a. Primary onlyb. Shoe-mounted secondary

c. Rim-mounted secondary

Internal floating roof tanks":1. Liquid-mounted resilient seal

a. Primary seal only

b. With rim-mounted secondary seal

2. Vapor-mounted resilient seal

a. Primary seal only

b. With rim-mounted secondary seal

Average

Ks(Ib-mol/

Fitting Sealsn

[mph]" ft yr)

1.2C

0.8

0.2

1.1

0.8

0.7

1.2

0.9

0.2

1.3

1.4

0.2

3.0

1.6

6.7f

2.5

1.5C

1.2

1.0

1.0

0.9

0.4

2.3

2.2

2.6

1.5

1.2

1.6

00

00

Tight Fitting Sealsb

Ks(Ib-mol/[mph]" ft yr)

0.8

0.8

0.2

0.5

0.5

0.5

1.0

1.1

0.4

d •

d

d

2.6

1.2

5.6

2.3

n

1.6

1.1

0.9

1.1

1.0

0.5

1.7

1.6

1.5

00

00

The rim seal factors (Ks, n) may be used for wind speeds from 2 to 15 mph.

No gaps more than 1/8 inch wide between the rim seal and the tank shell. Tight-fitting seal condition is unusual and difficult to verify.If no specific information is available, a welded tank with an average-fitting mechanical shoe primary seal only can be assumed to

represent the most common or typical tank constmction and rim seal system in use.No evaporative loss information is available for riveted tanks with consistently tight-fitting rim seal.

Based on emissions from tank seal systems in reasonable good working condition, no visible holes, tears, or unusually large gapsbehveen the seals and the tank wall.

If no specific information is available, a vapor-mounted primary seal only can be assumed to represent the most common or typical seal

system in use.

TABLE-5. Average CIingage

LiquidGasolme

Single-component stocks

Crude oil

factors (bb VI 000 ft2)

Light Rusta

0.00150.00150.0060

Shell ConditionDense Rust0.00750.00750.030

Gunite Lined

0.150.150.60

If no specific information is available, these values can be assumed to represent the most common condition of tanks currently in use.


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TABLE^_ExtEnaLROOfJ!tt"^^Roof Fitting Loss Factors

TypicalKfa Kfb m Number of

Roof Fitting Type and Construction Details Ib-mol/yr Ib-mol/yr - Fittings, Nfb

1. Access hatch (24-inch diameter well)a. Bolted cover, gasketed 0.0

b. Unbolted cover, ungasketed 2.7c. Unbolted cover, gasketed 2.9

2. Guide-pole well (8-inch diameter unslotted pole, 21-inch diameter well)

a. Ungasketed sliding cover 0b. Gasketed sliding cover 0

3. Guide-pole/sample well (8-inch-diameter unslottedpole, 21-inch-diameter well)

a. Ungasketed sliding cover, without float 0b. Ungasketed sliding cover, with float 0c. Gasketed sliding cover, without float 0d. Gasketed sliding cover, with float 0

4. Gauge float well (20-inch-diameter well)a. Unbolted cover, ungasketed 2.3b. Unbolted cover, gasketed 2.4c. Bolted cover, gasketed 0

5. Gauge hatch/sample well (8-inch-diameter well)a. Weighted mechanical actuation, gasketed 0.95b. Weighted mechanical actuation, ungasketed 0.91

6. Vacuum breaker (10-inch-diameter well)a. Weighted mechanical actuation, gasketed 1.2b. Weighted mechanical actuation, ungasketed 1.1

7. Roof drain (3 inch diameter)a. Open 0

b. Closed, 90% 0.518. Roof leg (3-inch-diameter leg)

a. Adjustable, pontoon area 1 .5b. Adjustable, center area 0.25c. Adjustable, double-deck roofs 0.25d. fixed 0

9. Roof leg (2.5-inch-diameter)a. Adjustable, pontoon area 1 .7b. Adjustable, center area 0.41c. Adjustable, double-deck roofs 0.41d. fixed 0

10. Rim vent (6-inch diameter)a. Weighted mechanical actuation, gasketed 0.71b. Weighted mechanical actuation, ungasketed 0.68

10.0

7.1

0.41

673.0

31029260

8.5

5.9

0.340

0.142.4

0.173.0

7.0

0.81

0.200.0670.0670

0000

0.101.8

o.ob

1.0

1.0

0.98b

1.4

1.2

2.0

1.2

2.4

1.0b

1.0

0

1.0b

1.0

1.0b

1.0

1.4e

1.0e

1.0b

1.0b

1.0

0

0000

1.0b

1.0

see Table-7

see Table-7

see Table-8

1.0d

° The roof fitting loss factors (Kra, Km, m) may be used only for wind speeds from 2 to 15 mph.b If no specific information is available, this value can be assumed to represent the most common or typical roof fittings currently in use.

c Guide-pole/sample well is an optional fitting not typically used.d Rim vents are used only with mechanical shoe primary seals.

° Roof drains that drain excess rainwater into the product are not used on pontoon floating roofs. They are, however, used on double-deck

floating roofs and are typically left "open".


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TAVLE-7.^yp\calNumb^^^^Tank Vacuum Breakers

Diameter, feetb Pontoon Roof Double-deck Roof Double-deck Roof50 1 1 1100 1 1 1150 2 2 2200 3 2 3250 4 3 5300 5 3 7350 64-400 74-

° This table was derived from a survey of users and manufacturers. The actual number of vacuum breakers may vary greatly depending on

throughput and manufacturing prerogatives. The actual number of roof drains may also vary greatly depending on the design rainfall

and manufacturing prerogatives. For tanks over 300 feet in diameter, actual tank data or the manufacturer's recommendations may beneeded for the number of roof drains. This table should not supersede information based on actual tank data.

b If the actual diameter is between the diameters listed in this table, use the closest diameter listed. If midway, use the next larger diameter.

c Roof drains than drain excess rainvvater into the product are not used on pontoon floating roofs. They are, however, used on double-deckfloating roofs and typically left "open".

TABLE-8. Typical Number of External Floating Roof Legs"

TankDiameter,feetb

304050

60708090100

110120130140150

160170180190200

Pontoon RoofPontoonLegs446

913151617

1819202123

2627282930

CenterLegs246

79101216

2024283338

4249566269

Double-

Deck Roof

678

1013162025

2934404652

5866748290

TankDiameter,

feet"

210220230240250260270280290300

310320330340350360370380390400

Pontoon

Pontoon

Legs31323334353636373838

39394041424445464748

RoofCenter

Legs778392101109118128138148156

168179190202213226238252266281

Double-

Deck Roof

98107115127138149162173186200

213226240255270285300315330345

' This table was derived from a survey of users and manufacturers. The actual number of roof legs may vary greatly depending on age,floating roof style, loading specifications, and manufacturing prerogatives. This table should not supersede information based on actual

tank data.If the actual diameter is between the diameters listed in this table, use the closest diameter listed. If midway, use the next larger diameter.



.T^^y^?^22l2!£!ZJ)Il!!lerna^

Deck Fitting TypeDeck Fitting Loss FactorKp (Ib-mole/yr)

Typical No. of FittingsNp

Access hatch (24-inch diameter)Bolted cover, gasketed 1.6

Unbolted cover, ungasketed 11Unbolted cover, gasketed 25b

Gauge float well(24-inch-diameter)B olted cover, gasketed 5 . 1

Unbolted cover, gasketed 15Unbolted cover, ungasketed 28b

Column well0 (24-inch diameter)Built-up column-sliding cover, gasketed 33Built-up column-sliding cover, ungasketed 47b

Pipe column-flexible fabric sleeve seal 10Pipe column-sliding cover, gasketed 19Pipe column-sliding cover, ungasketed 32.1

Ladder wellc (36-inch diameter)

Slidmg cover, gasketed 56Sliding cover, ungasketed 76b

Deck leg or hanger wellAdjustable 7.9bFixed 0

1

(see Table-5)

{5 + D/10 + (D2/600)}2

Sample pipe or well (24-inch diameter)Slotted pipe-slidmg cover, gasketed 44Slotted pipe-slidmg cover, ungasketed 57Sample well-slit fabric seal, 10% open area 12b

Stub drain (1-inch diameter)'1 1.2

Vacuum breaker (10-inch diameter)Weighted mechanical actuation, gasketed 0.7bWeighted mechanical actuation, ungasketed 0.9

(D2/125)d

1

' For wind speeds ranging from 2 to 15 mph.

b If no specific information is available, this value can be assumed to represent the most common/typical deck.

c Not used in welded contact internal floating decks.

d D = tank diameter, feet.


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TABLE-10. Deck Seam Length Factors for Typical Deck Constructionsfor Internal Floating Roof Tanks"

Deck Construction Typical Deck SeamLength Factors, SD (ft/ft2)

Continuous-sheet construction1'

5-foot-wide sheets 0.20°

6-foot-wide sheets 0.17

7-foot-wide sheets 0.14

Panel construction'1

5 by 7.5-foot rectangular 0.33

5 by 12-footrectangular 0.28" Deck seam loss applies to bolted decks only" SD = 1/W, where W = sheet width (feet).

c If no specific information is available, these factors can be assumed to represent

the most common bolted decks currently in use.

•' SD = (L +W)/LW, where W = panel width (feet) and L = panel length (feet).

TABLE-11. Saturation Factors for Calculating Petroleum Liquid Loading Losses

Carrier

Tank trucks andrail cars

Marine vessels

Mode of Operation

Submerged loading:Clean cargo tankDedicated normal serviceDedicated vapor balance service

Splash loadmg:Clean cargo tankDedicated normal service

Submerged loading:ShipsBarges

Saturation Factor

0.50

0.601.00

1.451.45

0.2

0.5

REFERENCES:

1. Compilation of Air Pollutant Emissions Factors, AP42,4th ed., U.S. Environmental Protection Agency, OAQPS, RTP, 9/85.2. Evaporation Loss from External Floating Roof Tanks, Bulletin 2517, 3rd cd., API, 2/89.

3. Evaporation Loss from Internal Floating Roof Tanks, Bulletin 2519,3rd ed., API, 6/83.

26-2029-TV-01

ISSUED BY THE DEPARTMENT OF ENVIRONMENTAL QUALITY

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