air emission permit no. 16300010-005 is issued to newport ... · losses, tank roof landing events,...

Technical Support Document, Permit Action Number: 16300010 ‐ 005 Page 1 of 9 Date: 5/29/2013

TECHNICAL SUPPORT DOCUMENT

For

AIR EMISSION PERMIT NO. 16300010‐005

This technical support document (TSD) is intended for all parties interested in the permit and to meet

the requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and

Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the legal and factual

justification for each applicable requirement or policy decision considered in the determination to issue

the permit.

1. General Information

1.1 Applicant and Stationary Source Location:

Table 1. Applicant and Source Address

Applicant/Address Stationary Source/Address

(SIC Code: 5171)

Newport Terminal Corp.

4567 American Boulevard West

Bloomington, MN 55437

Responsible Official: Mr. Richard A. Mills

Newport Terminal Corp.

50 21st St

Newport, MN 55055

Washington County

Contact: Mr. Bruce Anthony, Environmental

Director

Phone: 952‐830‐8899

1.2 Facility Description

Newport Terminal Corp. (NTC) is a bulk transfer and storage terminal for petroleum products (gasoline and diesel fuel). The facility consists of three ethanol storage tanks, seven gasoline storage tanks, two small tanks for gasoline additive and for diesel fuel storage, and a transfer station with two loading racks. A vapor recovery unit (VRU) is the primary VOC control device for gasoline truck loading rack. The VRU (CE 002) is a carbon adsorption system with the capability to recover gasoline vapors and return the recovered gasoline back to the facility’s gasoline storage tank system. VOC emissions from the VRU will be monitored by a CEMS unit (MR 002). Loading Rack 1 (used for blended gasoline loadout) also has a vapor collections system that vents to a flare with propane pilots. The facility operates under a federally enforceable state operating permit. Volatile Organic Compounds (VOC) are the main pollutant from the facility, including volatile Hazardous Air Pollutants (HAP). The VOCs are emitted from product loading, storage tank standing and working losses, tank roof landing events, fugitive emissions from valves, pumps, and flanges, tanker purging, and emergency generator operation. Ethanol and sub‐octane gasoline are blended as they are loaded into gasoline cargo tanks to produce 87 octane no lead regular gasoline with 10 percent ethanol and E‐85 gasoline with 85% ethanol.


The VOC emissions from unloading of gasoline from delivery trucks to gasoline service station storage tanks at service stations are collected and then displaced from the cargo tanker upon tanker refilling at the facility. Tankers may occasionally be purged of vapors to allow for maintenance, by pumping air into the tanker to displace the combustible vapors. These vapors cannot be vented to the flare during purging because this could create explosive mixtures in the vapor collection system as the air/gasoline vapor mixture pass through the explosive range. NTC is a petroleum storage and transfer unit with a total storage capacity exceeding 300,000 barrels (equivalent to 12.6 mmgal) and therefore is one of the 28 listed source categories under new source review. As a result the facility is subject to the 100 tpy major source threshold of a regulated pollutant, including fugitives. The limited controlled VOC emissions are below PSD major source threshold (100tpy) to avoid PSD permitting requirements.

1.3 Description of the Activities Allowed by this Permit Action

This permit action is a major amendment to install a 619 HP diesel emergency generator (EU 004). The main pollutants of concern from internal combustion engines are VOC, carbon monoxide (CO), sulfur dioxide (SO2), and nitrogen oxides (NOX). The emergency generator is included under the total facility VOC limit of 95 tpy so that NTC will remain a synthetic minor source under PSD. NTC will maintain compliance by installing a non‐resettable hour meter on EU 004 and recording the monthly hours of operation. In addition, this permit action includes a minor amendment for installation of soil vapor extraction unit. Since NTC submitted this minor permit application, the soil vapor extraction unit has been removed and therefore no requirements were included within the permit. Also included is an initial notification for 40 CFR pt. 63, subp. BBBBBB and a reopening for a notice of compliance and test frequency plan. The necessary changes that would have resulted from these actions were completed in the previous permit amendment, and no other changes were incorporated in this permit action.

1.4. Facility Emissions:

Table 2. Total Facility Potential to Emit Summary

PM

tpy

PM10

tpy

PM2.5

tpy

SO2

tpy

NOx

tpy

CO

tpy

CO2e

Tpy

VOC

tpy

Single

HAP

tpy

All

HAPs

tpy

Total Facility

Limited Potential

Emissions

0.05 0.06 0.06 1.25 5.35 12.77 4,065 95 1.58 3.44

Total Facility

Actual Emissions

(2012)

0.0 0.0 0.0 0.0 0.0 0.0 * 71.2 *


* Not reported in MN emission inventory.

Table 5. Facility Classification

Classification Major/Affected

Source

Synthetic Minor/Area Minor/Area

PSD VOC PM, PM10, PM2.5,

SO2, NOx, Lead

Part 70 Permit Program VOC PM10, PM2.5, SO2,

NOx, Lead

Part 63 NESHAP HAPs

2. Regulatory and/or Statutory Basis

New Source Review

The facility is an existing synthetic minor source under New Source Review regulations. No changes are

authorized by this permit.

Part 70 Permit Program

The facility is an existing synthetic minor source under the Part 70 permit program. No changes are

authorized by this permit.

New Source Performance Standards (NSPS)

The diesel emergency generator is subject to 40 CFR pt. 60, subp. IIII. Of the applicable requirements, 40

CFR Section 89.113 applies to NTC according to 40 CFR Section 60.4205(b). However, 40 CFR Section

89.113(c) states that constant‐speed engines are exempt from the requirements of 40 CFR Section

89.113. Under 40 CFR Section 89.2, constant‐speed engines are defined as engines that are governed to

operate only at rated speed. EU 004 is considered a constant‐speed engine designed to operate at 1,800

RPM that will generate electricity at a specified voltage and frequency. EU 004 will contain a control

system that includes a governor that controls engine speed by controlling the amount of fuel that is

delivered by the injectors. In addition, the governor is preset at the factory. Moreover, EU 004 will

contain a permanently affixed label that states, “constant‐speed only” and satisfies the requirement for

40 CFR Section 89.110(b)(11). Therefore, 40 CFR Section 60.4205(b) opacity limits do not apply to EU

004. Attachment 4 of the TSD contains documentation of the engine control system, generator

performance data and an image of the permanently affixed label.

National Emission Standards for Hazardous Air Pollutants (NESHAP)

The facility has accepted limits on HAP emissions such that it is an area source under 40 CFR pt. 63.

Thus, no major source NESHAPs apply. The diesel emergency generator is subject to the area source

NESHAP for 40 CFR pt. 63, subp. ZZZZ.


Compliance Assurance Monitoring (CAM)

CAM does not apply to the modification allowed in this permit amendment, because control equipment

will not control emissions from the diesel emergency generator.

Environmental Review & AERA

The facility has accepted limits on production such that it is not subject to environmental review, i.e. an

Environmental Assessment Worksheet (EAW,) and is not required to perform an Air Emissions Risk

Analysis (AERA).

Minnesota State Rules

Portions of the facility are subject to the following Minnesota Standards of Performance:

Minn. R. 7011.1505 Standards of Performance for Liquid Storage Vessels

Minn. R. 7011.1550 Standards of Performance for New Bulk Gasoline Terminals

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines

Table 6. Regulatory Overview of Units Affected by the Modification/Permit Amendment

Level* Applicable Regulations Comments:

Total Facility

Title I Condition: To avoid classification as major source

under 40 CFR Section 52.21 and Minn. R. 7007.3000; To

avoid classification as a major source under 40 CFR Section

70.2 and Minn. R. 7007.0200; To avoid major source

classification under 40 CFR Section 63.2; Minn. R.

7007.0800, subps. 4 and 5

Total facility limit of 95 tpy VOC emissions on a 12‐month rolling sum basis.

EU 004 Title I Condition: To avoid classification as major source

under 40 CFR Section 52.21 and Minn. R. 7007.3000; To

avoid classification as a major source under 40 CFR Section

70.2 and Minn. R. 7007.0200; To avoid major source

classification under 40 CFR Section 63.2; Minn. R.

7007.0800, subps. 4 and 5

Monitoring and recordkeeping of throughput and emissions of VOC

40 CFR pt. 63, subp. ZZZZ; Minn. R. 7011.8150 National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines

40 CFR pt. 60, subp. IIII New Source Performance Standards for Stationary Compression Ignition Internal Combustion Engines


Level* Applicable Regulations Comments:

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines.

*Where the requirement appears in the permit (e.g., EU, SV, GP, etc.).

3. Technical Information

3.1 Calculations of Potential to Emit

Emission calculations for this project are included in Attachment 1 to this TSD. NTC plans to install the diesel generator Caterpillar model C15 400 ekW at 60 Hz operation. Manufacturer provided emission factors were used to calculate emissions of nitrogen oxides (NOx), carbon monoxide (CO), hydrocarbons (HC), and filterable particulate matter (PM). The manufacturer information is given in Attachment 4 to this TSD. In addition, the condensable PM emission factor was obtained from US EPA WebFIRE for a diesel engine. This emission factor was added to the filterable PM, particulate matter less than 10 microns (PM10), and particulate matter less than 2.5 microns (PM2.5) emission factors, to calculate total emissions of these pollutants.

3.2 Periodic Monitoring

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have

sufficient knowledge of the facility to certify that the facility is in compliance with all applicable

requirements.

In evaluating the monitoring included in the permit, the MPCA considered the following:

The likelihood of the facility violating the applicable requirements;

Whether add‐on controls are necessary to meet the emission limits;

The variability of emissions over time;

The type of monitoring, process, maintenance, or control equipment data already available for the emission unit;

The technical and economic feasibility of possible periodic monitoring methods; and

The kind of monitoring found on similar units elsewhere.

The table below summarizes the periodic monitoring requirements for those emission units for which

the monitoring required by the applicable requirement is nonexistent or inadequate.

Table 7. Periodic Monitoring

Level* Requirement (rule basis) Additional

Monitoring

Discussion

Total Facility

VOC: <95.0 tpy on a 12‐month rolling sum Title I Condition: To avoid

classification as major source

Monthly summation of VOC emissions from facility VOC emission sources

Calculation of total facility VOC emissions by the 15th day of each month will allow NTC to demonstrate compliance with the 95 tpy limit. NTC must calculate



Monitoring

Discussion

under 40 CFR Section 52.21 and

Minn. R. 7007.3000; To avoid

classification as a major source

under 40 CFR Section 70.2 and

Minn. R. 7007.0200; To avoid

major source classification under

40 CFR Section 63.2; Minn. R.

7007.0800, subps. 4 and 5

emissions using a 12‐month rolling sum.

GP 001 Title I Condition: to avoid major source status under Sections 52.21 and 63.2; Minn. R. 7007.0800, subp. 2 to avoid part 70 major source status

Monthly calculation of storage tank throughput and VOC emissions

Calculation of storage tank throughput and VOC emissions by the 15th day of each month will allow the Permittee to demonstrate compliance with the total facility 95 tpy limit.

EU 001 and CE 002

Title I Condition: to avoid major source status under Sections 52.21 and 63.2; Minn. R. 7007.0800, subp. 2 to avoid part 70 major source status

Monthly calculation of gasoline throughput and VOC emissions

Calculation of Loading Rack 1 gasoline throughput and VOC emissions by the 15th day of each month will allow the Permittee to demonstrate compliance with the total facility 95 tpy limit.

40 CFR Part 60 Subpart XX; Minn. R. 7011.1550

None This new source performance standard contains adequate monitoring to ensure vapor capture and control from the loading of gasoline tanker trucks. This includes performance testing to verify compliance with the 35 mg/liter VOC limit and maximum cargo tank pressure of 4,500 pascals during gasoline tanker loading.

EU 002 Monthly calculation of diesel fuel throughput and VOC emissions

Calculation of Loading Rack 2 diesel fuel throughput and VOC emissions by the 15th day of each month will allow the Permittee to demonstrate compliance with the total facility 95 tpy limit.



Monitoring

Discussion

CE 001 Title I Condition: to avoid major

source status under Sections

52.21 and 63.2; Minn. R.

7007.0800, subp. 2 to avoid part

70 major source status

Monitoring to

verify presence of

flame for control of

VOCs

Flame presence indicates that the

flare is operating and controlling

VOC vapors collected from the

vapor collection system associated

with Loading Rack 1.

FS 001 Title I Condition: to avoid major source status under Sections 52.21 and 63.2; Minn. R. 7007.0800, subp. 2 to avoid part 70 major source status

Monthly calculation of VOC emissions from valves, flanges, & pump seals in service

Calculation of VOC leaks from seals, flanges, and valves by the 15th day of each month will allow NTC to demonstrate compliance with the total facility 95 tpy limit.

FS 002 Title I Condition: to avoid major


52.21 and 63.2; Minn. R.



Monthly calculation of tanker purging VOC emissions

Calculation of tanker purging VOC

emissions by the 15th day of each

month will allow the Permittee to

demonstrate compliance with the

total facility 95 tpy limit.

EU 004 Title I Condition: to avoid major


52.21 and 63.2; Minn. R.



Monthly calculation of VOC emissions

Calculation of VOC emission based on the monthly hours of operation. The emission factor for VOC emissions comes from the most recent AP‐42 emission factors for large stationary diesel and all stationary dual‐fuel engines. NTC will install a non‐resettable hour meter.

Hours of Operation: < 500

hours/year; Title I Condition: to

avoid major source status under

Sections 52.21 and 63.2; Minn. R.



Recordkeeping of hours operated

NMHC+NOX: < to 4.0 g/kw‐hr

exhaust emissions; 40 CFR

Section 60.4205(b)

NTC will purchase diesel fuel that meets the requirements of 40 CFR Section 80.510(b) for nonroad diesel fuel. NTC will also obtain and maintain a fuel supplier certification for each shipment of diesel fuel certifying that the sulfur content does not exceed 0.0015% by weight.

CO: < to 3.5 g/kw‐hr exhaust

emissions; 40 CFR Section

60.4205(b)

Total PM: < to 0.2 g/kw‐hr



Monitoring

Discussion

exhaust emissions; 40 CFR

Section 60.4205(b)

NTC will also purchase an engine certified to the emission standards in 40 CFR Section 60.4205(b) and install and configure EU 004 according to the manufacturer's emission‐related specifications.

Opacity: < to 20 percent once

operating temperatures have

been attained; Minn. R.

7011.2300

SO2: < 0.5 lbs/MMBtu; Minn. R.

7011.2300

*Where the requirement appears in the permit (e.g., EU, SV, GP, etc.).

3.3 Insignificant Activities Newport Terminal Corp. has several operations which are classified as insignificant activities under the

MPCA’s permitting rules. The insignificant activities, including justification why no additional periodic

monitoring is necessary for these insignificant activities, are listed in Appendix II to the permit.

3.4 Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Delta guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in Table A or B of the permit. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these.

3.6 Comments Received

Public Notice Period: 04/18/2013 – 05/17/2013 EPA 30‐day Review Period: 04/18/2013 – 05/17/2013

Comments were received from the public during the public notice period. The comments received did

not include adverse comments on any applicable requirements of the permit. Changes to the permit

were made as a result of the comments; however these changes could have been accommodated by the

procedures for administrative amendments in Minn. R. 7007.1400, subpart 1. The following are

comments that were received;

1) Revise facility description to the cover of the draft permit to match the description in the Technical Support Document (TSD). The TSD description includes the VRU, the draft permit description does not.

2) Delete repetitive requirements on page 21 of the CD‐01, item 37 of EU 004. These requirements are also included as item 39.

3) Add “if” to page 23 of the CD‐01, item 45 of EU 004. 4) On page 6 of the CD‐01, item 4 of GP 001, under “Working Losses Calculation”, replace

“standing” with “working” in the first line.


All suggested changes to the permit were made in response to the comments received.

4. Permit Fee Assessment

Attachment 3 to this TSD contains the MPCA’s assessment of Application and Additional Points used to determine the permit application fee for this permit action as required by Minn. R. 7002.0019. The permit action includes two permit applications, one that was received after the effective date of the rule (July 1, 2009). The permit includes the incorporation of a NESHAP that was triggered by the modification authorized by the amendment applications. The other permit application was a minor amendment application that was received August 28, 2003, before the effective date of the rule. No significant changes were required under this permit amendment, so no additional points were charged. This permit action also includes a initial NESHAP notification and a reopening . The necessary changes that would have resulted from these actions were completed in the previous permit amendment, and no other changes were incorporated in this permit action, so no additional points were charged.

5. Conclusion

Based on the information provided by Newport Terminal Corp., the MPCA has reasonable assurance

that the proposed operation of the emission facility, as described in the Air Emission Permit No.

16300010‐005 and this TSD, will not cause or contribute to a violation of applicable federal regulations

and Minnesota Rules.

Staff Members on Permit Team: Andrea Walkush (permit writer/engineer)

Sarah Kilgriff (enforcement)

Marc Severin (stack testing)

Sarah Seelen (peer reviewer)

AQ File No. 1068; DQ 4146, 2784, 2301, 2725

Attachments: 1. PTE Summary Calculation Spreadsheets 2. Facility Description and CD‐01 Forms 3. Points Calculator 4. Caterpillar Diesel Generator Information

Technical Support Document, Permit Action Number: 16300010‐005

Attachment 1: PTE Summary Calculation Spreadsheets

Newport Terminal

Source SOx NOx CO PM PM-10 PM-2.5 VOC CO2 CH4 N2O CO2-e Single HAP Total HAPlb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/hr lb/yr

TK012 No 1 & 2 FO (TK012) [Insignificant] 11 0.62 1.17TK013 Gasoline Additive (TK013) [Insignificant] 21 0.39 0.85TK001 Tank 103 Ethanol (TK001) 6,323 0.00 0TK002 Tank 104 Ethanol (TK002) 6,323 0.00 0TK003 Tank 105 Ethanol (TK003) 6,323 0.00 0TK004 Tank 106 Gasoline (TK004) 4,386 80.71 175TK005 Tank 107 Gasoline (TK005) 6,718 123.61 269TK006 Tank 108 Gasoline (TK006) 6,718 123.61 269TK007 Tank 109 Gasoline (TK007) 6,718 123.61 269TK008 Tank 110 Gasoline (TK008) 6,718 123.61 269TK009 Tank 111 Gasoline (TK009) 6,616 121.73 265TK010 Tank 112 Gasoline (TK010) 6,718 123.61 269

IFR Tank Roof LandingsTanks 106-112 Gasoline 5,326 98.00 213Tank 106 Gasoline 0Tank 107 Gasoline 0Tank 108 Gasoline 0Tank 109 Gasoline 0Tank 110 Gasoline 0Tank 111 Gasoline 2,663Tank 112 Gasoline 2,663

EU001 Loading Rack 1Gasoline Vapor Combustion at Flare [2] 2,492 10,196 25,490 102 102 102 119,909 8,036,630 343.35 68.67 8,065,128 2,206.33 4,796Pilot Gas (propane) 0.09 71 10 2 2 2 incl. above 31.13 0.00 0 31 incl. above incl. above

2,492 10,267 25,500 104 104 104 119,909 8,036,661 343.35 69 8,065,159 2,206.33 4,796.37

Fuel Oil DispenserFuel Oil Loading [Insignificant] 10.56 0.59 1.14

Fugitive ComponentsFittings [Insignificant] - VRU Included 486 27.28 55.34

Emergency Generator [1] 1 434 43 7 7 35 358,894 14.56 2.91 360,103 0.30 0.92

Tanker Purging 831 15.29 33

TOTAL (lb/yr) 2,493 10,700 25,543 104 111 111 190,190 8,395,555 358 72 8,425,262 3,169 6,886TOTAL (tons/yr) 1.25 5.35 12.77 0.05 0.06 0.06 95.10 4,198 0.18 0.04 4,213 1.58 3.44

[1] Updated based on MPCA Comments from 2-12-2013 e-mail to Bruce Anthony from Andrea Walkush. SO2 emission rate updated to 0.5 lb SO2/MMBtu per 2-21-2013 email from Andrea Walkus[2] Emission calculations based on use of flare to control loading rack VOC emissions; actual emissions with VRU in service will be lower (Added note for clarification 2/25/2013; no change in emission calculations

Table 1. Facility Projected Actual Emission Summary (in pounds per year unless otherwise specified in the table)

Criteria Pollutants Hazardous Air Pollutants (HAP)

EC AttachmentPage 1 of 30

Newport Terminal

Source SOx NOx CO PM PM-10 PM-2.5 VOC CO2 CH4 N2O CO2-e Pb Single HAP Total HAPlb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr

Storage TanksTK012 No 1 & 2 FO (TK012) [Insignificant] 11 0.62 1.17TK013 Gasoline Additive (TK013) [Insignificant] 21 0.39 0.85TK001 Tank 103 Ethanol (TK001) 6,323 0.00 0TK002 Tank 104 Ethanol (TK002) 6,323 0.00 0TK003 Tank 105 Ethanol (TK003) 6,323 0.00 0TK004 Tank 106 Gasoline (TK004) 4,386 80.71 175TK005 Tank 107 Gasoline (TK005) 6,718 123.61 269TK006 Tank 108 Gasoline (TK006) 6,718 123.61 269TK007 Tank 109 Gasoline (TK007) 6,718 123.61 269TK008 Tank 110 Gasoline (TK008) 6,718 123.61 269TK009 Tank 111 Gasoline (TK009) 6,616 121.73 265TK010 Tank 112 Gasoline (TK010) 6,718 123.61 269

IFR Tank Roof LandingsTanks 106-112 Gasoline 5,326 98.00 213Tank 106 Gasoline 0Tank 107 Gasoline 0Tank 108 Gasoline 0Tank 109 Gasoline 0Tank 110 Gasoline 0Tank 111 Gasoline 2,663Tank 112 Gasoline 2,663

EU001 Loading Rack 1Gasoline Vapor Combustion at VRU 249 1,020 2,549 10 10 10 62,874 803,663 34.33 6.87 806,513 --- 1,156.87 2,515Pilot Gas (propane) 0.01 7 1 0 0 0 incl. above 3.11 0.00 0.00 3.13 0 incl. above incl. above

249 1,027 2,550 10 10 10 62,874 803,666 34.33 6.87 806,516 0.00 1,156.87 2,514.94

Fuel Oil DispenserFuel Oil Loading [Insignificant] 10.56 0.59 1.14

Fugitive ComponentsFittings [Insignificant] 486 27.28 55.34

Emergency Generator 1 434 43 7 7 35 358,894 14.56 2.91 360,103 0.30 0.92

Tanker Purging 831 15.29 33

TOTAL (lb/yr) 249 1,027 2,550 10 10 10 133,119 803,666 34 7 806,516 0 2,120 4,603TOTAL (tons/yr) 0.12 0.51 1.28 0.01 0.01 0.01 66.56 402 0.02 0.00 403 0 1.06 2.30

SOx NOx CO PM PM-10 PM-2.5 VOC CO2 CH4 N2O CO2-e Pb Single HAP Total HAP

Facility Projected Actual Emission Summary with Diesel Generator and VRU in Service (in pounds per year unless otherwise specified in the table)


Engine: Engine hp:

Engine mmBtu/hr

[1]:

Potential Emergency Operating

Hrs/Yr

Max (Limited

PTE) Hrs/Yr

Actual Hrs/Yr [6]

CAT C15 ATAAC 400 ekW 619.00 4.33 500.00 500.00 90.00

Pollutant

Emission Factor (lb/ MMBtu) [2]

Emission Factor

(g/hp-hr) [3]

Capacity (MMBtu

/hr)

Emission Rate

(lb/hr) PTE (tpy)Limited

PTE (tpy)Actual (tpy)

NOX - 3.53 4.33 4.82 1.20 1.20 0.22CO - 0.35 4.33 4.78E-01 1.19E-01 1.19E-01 2.15E-02PM - 0.058 4.33 7.96E-02 1.99E-02 1.99E-02 3.58E-03

PM10 - 0.058 4.33 7.96E-02 1.99E-02 1.99E-02 3.58E-03

PM2.5 - 0.058 4.33 7.96E-02 1.99E-02 1.99E-02 3.58E-03

SO2[4] 5.00E-01 - 4.33 2.17E+00 5.42E-01 5.42E-01 2.95E-04

VOC 0.09 - 4.33 3.90E-01 9.75E-02 9.75E-02 1.75E-02

Benzene 7.76E-04 - 4.33 3.36E-03 8.41E-04 8.41E-04 1.51E-04Toluene 2.81E-04 - 4.33 1.22E-03 3.04E-04 3.04E-04 5.48E-05Xylene 1.93E-04 - 4.33 8.36E-04 2.09E-04 2.09E-04 3.76E-051,3-Butadiene 3.91E-05 - 4.33 1.69E-04 4.24E-05 4.24E-05 7.62E-06Formaldehyde 7.89E-05 - 4.33 3.42E-04 8.55E-05 8.55E-05 1.54E-05Acetaldehyde 2.52E-05 - 4.33 1.09E-04 2.73E-05 2.73E-05 4.91E-06Acrolein 7.88E-06 - 4.33 3.41E-05 8.54E-06 8.54E-06 1.54E-06Naphthalene 1.30E-04 - 4.33 5.63E-04 1.41E-04 1.41E-04 2.53E-05Acenaphthylene 9.23E-06 - 4.33 4.00E-05 1.00E-05 1.00E-05 1.80E-06Acenaphthene 4.68E-06 - 4.33 2.03E-05 5.07E-06 5.07E-06 9.13E-07Fluorene 1.28E-05 - 4.33 5.55E-05 1.39E-05 1.39E-05 2.50E-06Phenanthrene 4.08E-05 - 4.33 1.77E-04 4.42E-05 4.42E-05 7.96E-06Anthracene 1.23E-06 - 4.33 5.33E-06 1.33E-06 1.33E-06 2.40E-07Fluoranthene 4.03E-06 - 4.33 1.75E-05 4.37E-06 4.37E-06 7.86E-07Pyrene 3.71E-06 - 4.33 1.61E-05 4.02E-06 4.02E-06 7.23E-07Benzo(a)anthracene 6.22E-07 - 4.33 2.70E-06 6.74E-07 6.74E-07 1.21E-07Chrysene 1.53E-06 - 4.33 6.63E-06 1.66E-06 1.66E-06 2.98E-07Benzo(b)fluoranthene 1.11E-06 - 4.33 4.81E-06 1.20E-06 1.20E-06 2.16E-07Benzo(k)fluoranthene 2.18E-07 - 4.33 9.45E-07 2.36E-07 2.36E-07 4.25E-08Benzo(a)pyrene 2.57E-07 - 4.33 1.11E-06 2.78E-07 2.78E-07 5.01E-08Indeno(1,2,3-cd)pyrene 4.14E-07 - 4.33 1.79E-06 4.48E-07 4.48E-07 8.07E-08Dibenzo(a,h)anthracene 3.46E-07 - 4.33 1.50E-06 3.75E-07 3.75E-07 6.75E-08Benzo(g,h,l)perylene 5.56E-07 - 4.33 2.41E-06 6.02E-07 6.02E-07 1.08E-07POM 8.15E-05 - 4.33 3.53E-04 8.83E-05 8.83E-05 1.59E-05

Total HAPs 7.34E-03 1.84E-03 1.84E-03 4.59E-04Single Largest HAP [5] 3.36E-03 8.41E-04 8.41E-04 1.51E-04

Notes:

[6] Actual operating hours include the 50 non-emergency operating hours allowed under 40 CFR 60 Subpart IIII and an estimated 40 emergency hours per year. Revised from original submittal (500 hours) per MPCA request e-mail, dated 2-12-2013.

Table 7. Emergency Generator Potential Emission Calculations (2 pages)Newport Terminal, Revised Per MPCA Request 2-15-2013

EPA Certification Level and Engine Certification

YearTier 3, 2006

Criteria Air Pollutants

Hazardous Air Pollutants

[1] Calculated using EPA AP-42 Table 3.3.-1 conversion factor of 7,000 Btu/hp-hr.[2] Diesel emission factors taken from EPA AP-42 Section 3.4 Large Station Diesel ... Engines Tables 3.4-1 through 3.3-4.[3] NOx, CO, HC, and filterable PM emission factors are provided by the engine manufacturer, Caterpillar model C15 400 ekW at 60 Hz operation. For consistency with NSPS Subpart IIII for model years newer than 2007, the NOx emission factor used is NOx+HC. The condensable PM emission factor provided in US EPA WebFIRE for a diesel engine (only one factor available) was added to each of the engines' filterable PM emission factors, to calculate total PM.

[4] PTE for SO2 based on MN. R. 7011.2300 limitation of 0.5 lb SO2/MMBtu Heat Input. Revised from original submittal (15 ppm S) per MPCA request e-mail, dated 2-21-2013. Acutual SO2 emissions for diesel engines are based on the use of ultra-low sulfur distillate fuel with a sulfur content of 15 ppm (0.0015%). The Newport Terminal only has ultra low sulfur distillate fuel on site and would use this fuel in the generator.

[5] The highest single HAP for the diesel engines is benzene.


Gasoline CombustionPotential Gasoline Vapors Combusted at

Loading Rack: 2,491,865 lb/yr gasoline vaporsDensity of gasoline: 6 lb/gal

Flare Uptime: 100%Gasoline Vapors Combusted: 415,311 gal/yr

Propane CombustedFlare pilot gas flow: 0.58 gal/hr

Flare pilot hours of operation: 8,760 hr/yrFlare Uptime: 100%

Propane Combusted: 5,050 gal/yr

Diesel CombustedDiesel fuel flow @ 100% load: 31.9 gal/hr

Estimated actual engine hours of operation: 90 hr/yrPotential engine hours of operation: 500 hr/yr

Diesel Combusted: 15,950 gal/yr

PollutantHHV

(MMBtu/gal)

Emission Factor

(kg CO2/MMBtu)

Potential Emissions

(kg/yr)

Potential Emissions

(tpy)CO2e GWP

Existing Potential Emissions CO2e

(tpy)

Future Limited Emissions CO2e

(tpy)

Gasoline CO2 0.125 70.22 3,645,391 4,018 1 4,018 4,018CH4 0.125 3.0E-03 156 0.17 21 4 3.6N2O 0.125 6.0E-04 31 0.03 310 11 11

PropaneCO2 0.091 61.46 14 0.02 1 0.02 0.02CH4 0.091 3.0E-03 6.9E-04 7.6E-07 21 1.6E-05 1.6E-05N2O 0.091 6.0E-04 1.4E-04 1.5E-07 310 4.7E-05 4.7E-05

DieselCO2 0.138 73.96 162,793 179.4 1 179.4CH4 0.138 3.0E-03 7 7.3E-03 21 1.5E-01N2O 0.138 6.0E-04 1 1.5E-03 310 4.5E-01

TotalCO2 4018 1 4018 4198CH4 0.17 21 4 4N2O 0.03 310 11 11

4,033 4,213

Updated based on MPCA Comments from 2-12-2013 e-mail to Bruce Anthony from Andrea Walkush.

Potential GHG Emission Calculations Newport Terminal

Table 6. Hazardous Air Pollutant (HAP) Potential Emission Calculations Newport Terminal

Total VOCs lb/yr tons/yrFrom Gasoline Tanks: 169,848 84.92 Gasoline Loading, Tanks 106,107,108,109,110,111,112 & Detergent Additive Tank

From Fuel Oil Activities: 22 0.011 Tank B and Diesel Fueling RackFugitive Emissions: 486 0.24 Fittings

Emergency Generator: 35 1.75E-02 CombustionTanker Purging: 831 0.42 Gasoline tankers

Pollutant Emission Factors (lb HAP/lb VOC) (1) Gasoline Fuel Oil Gasoline or Fuel Oil (2) TotalGasoline Fuel Oil Max lb/yr tons/yr lb/yr tons/yr lb/yr tons/yr lb/yr tons/yr

Benzene 0.0077 0.0257 0.0257 1,314 0.66 0.55 0.00 12.50 0.01 1,327 0.66 Toluene 0.0066 0.0206 0.0206 1,126 0.56 0.44 0.00 10.02 0.01 1,137 0.57

Ethylbenzene 0.0004 0.0032 0.0032 68 0.03 0.07 0.00 1.56 0.00 70 0.03

Xylene (mixed isomers) 0.0015 0.0000 0.0015 256 0.13 - - 0.73 0.00 257 0.13 o-Xylene 0.0005 0.0013 0.0013 85 0.04 0.03 0.00 0.63 0.00 86 0.04 n-Hexane 0.0184 0.0561 0.0561 3,140 1.57 1.21 0.00 27.28 0.01 3,169 1.58

Cumene (Isopropylbenzene) 0.0000 0.0005 0.0005 - - 0.01 0.00 0.24 0.00 0 0.00

2,2,4-Trimethylpentane 0.0049 0.0000 0.0049 836 0.42 - - 2.38 0.00 839 0.42

Total HAPs = 3.44 Notes:1) The emission factors for gasoline are from EPA's SPECIATE software, profile 1014 (Gasoline - Summer Blend). Note that EPA uses this profile in AP-42, Section 7, for VOC emissions from gasoline storage tanks. The emission factors for fuel oil are conservatively estimated from EPA's SPECIATE software, profile 2488 (Composite of 9 Emission Profiles from Distillate Oil Storage Tanks).2) Since the fugitive (fittings and oil/water separator) activities could be associated with either gasoline or fuel oil, HAP emissions are calculated using the highest emission factor of the two materials.

Example Calculation: Total VOCs (lb/yr) x Benzene Emission Factor (lb HAP/lb VOC) = Benzene (lb/yr)


Working (lb/yr) Standing (lb/yr) (lb/yr) (tons/yr)Ethanol TK 001 10,191,679 4,790 1,533 --- 6,323 3.16 Ethanol TK 002 10,191,679 4,790 1,533 --- 6,323 3.16 Ethanol TK 003 10,191,679 4,790 1,533 --- 6,323 3.16

Withdrawal

Rim Seal + Deck Fitting + Deck

SeamGasoline (RVP 13) TK 004 22,931,277 69.37 4,317 - 4,386 2.19 Gasoline (RVP 13) TK 005 50,448,810 101.81 6,616 - 6,718 3.36 Gasoline (RVP 13) TK 006 50,448,810 101.81 6,616 - 6,718 3.36 Gasoline (RVP 13) TK 007 50,448,810 101.81 6,616 - 6,718 3.36 Gasoline (RVP 13) TK 008 50,448,810 101.81 6,616 - 6,718 3.36 Gasoline (RVP 13) TK 009 Not in service Not in service 6,616 2,663 6,616 3.31 Gasoline (RVP 13) TK 010 50,448,810 101.81 6,616 2,663 6,718 3.36

Working StandingGasoline Additive TK 013 72,270 8.30 13.03 --- 21.3 0.01

No. 1&2 Fuel Oil TK 012 600,000 8.63 2.36 --- 11.0 0.005

TOTAL 31.80

Notes:

1) The emissions for working and standing losses were calculated using Tanks Version 4.09 (see attached model runs). No tanks are subject to NSPS.2) 2006 Throughput + 33% (gal/yr) = 305,750,362

10% ethanol (gal/yr)= 30,575,03690% gasoline (gal/yr)= 275,175,326

Table 3. Potential Emission Calculations for TanksNewport Terminal

Material Tank ID

Throughput (gal/yr) (2)

VOC Emissions(1)

Landings (lb/yr)Total Emissions


Current Gasoline Throughput Limit 343,812.00 gal/day

TV TV Proposed Proposed

Max Max Max Max

Vol Turnovers Throughput Throughput Turnovers Throughput Throughput

(gal) (Gal/yr) (Gal/day) (Gal/yr) (Gal/day)

504,000.00 185.830 93,658,352.00 33.33 256,598.22 42.674 10,950,000.00 34,000.00 *

504,000.00 21.726 93,658,352.00 33.33 256,598.22 0.000 10,950,000.00 34,000.00

504,000.00 21.726 93,658,352.00 33.33 256,598.22 0.000 10,950,000.00 34,000.00

1,512,000.00 280,975,056.00 769,794.67 32,850,000.00 102,000.00

1,081,394.14 36.453 39,420,000 8.33 108,000.00 22.783 24,637,500 57,692.28

2,350,230.96 36.900 86,724,000 18.33 237,600.00 23.063 54,202,500 125,384.62 **

2,350,230.96 36.900 86,724,000 18.33 237,600.00 23.063 54,202,500 125,384.62

2,350,230.96 36.900 86,724,000 18.33 237,600.00 23.063 54,202,500 125,384.62

2,350,230.96 36.900 86,724,000 18.33 237,600.00 23.063 54,202,500 125,384.62

2,350,230.96 0.000 0 0.00 0.00 0.000 0 125,384.62

2,350,230.96 36.900 86,724,000 18.33 237,600.00 23.063 54,202,500 125,384.62 8.33333333

15,182,779.90 473,040,000.00 1,296,000.00 295,650,000.00 810,000.00 18.3333333

5,949.00 12.148 420,000.00 1,150.68 72,270.00 198.00 ***

17,000.00 600,000.00 1,643.84

16,921.66

NOTES:

* Assumed 900,000 gal/day at 10% ethanol + 10000 gal/day for E-85, rounded to 34000 gal/day/tank

** Rack Limit = 900,000 gal/day = 810,000 gal gas and 90,000 ethanol

*** Gal/year = 2.2e-4 * gal loaded

Percent Total Throughput


VOC Emissions from Gasoline Vapors - No. 1 Loading Rack NotesMaximum Physical Throughput Capacity (gal/day): 1,795,200 Basis: four 8500-gal trucks loaded per 30 min for

24 hours with a 10% safety factor.Maximum Annual Throughput (gal/yr): 655,248,000 Assumes year-round operation at maximum throughput.Projected Annual Throughput (gal/yr): 305,750,362 Assumes 2006 throughput plus a 33% increase.

Loading Rack Operation

Maximum Annual

Throughput (gal/yr)Vapor Collection

Efficiency (%)VOC Emission Factor (mg/L)

Factor (lb/1000 gal)

Emission Rate (lb/yr)

Emission Rate (tpy)

Controlled 301,775,607 98.7 35 0.29 87,515 43.76Uncontrolled 3,974,755 --- n/a 8.15 32,394 16.20

Total VOC Emissions: 119,909 59.95

Criteria Pollutant Emissions from Combustion of Gasoline VaporsLoading Rack Throughput with Flare Usage: 305,750,362 gal/yr

1,157,265,119 liter/yrLoading Rack Loss: 8.15 lb/1000 gal (See calculation on next page.)

Maximum Combusted Gasoline Vapors: 2,491,865 lb/yr

Pollutant Emissions EmissionsEmission Factor (lb/yr) (TPY)

SO2 500 ppmw (1) 2,491.87 1.25NOx 4 mg/l (2) 10,196.17 5.10CO 10 mg/l (2) 25,490.42 12.75PM 40 ug/l (3) 101.96 0.05

PM-10 40 ug/l (3) 101.96 0.05PM-2.5 40 ug/l (3) 101.96 0.05

Notes:(1) Use 500 ppmw sulfur in gasoline for SO2 emissions.(2) Manufacturer's guaranteed emissions level(3) Emission Factors from AP-42, Table 13.5-1, Industrial Flare Operations.Assumes throughput displaces equivalent amount of vapors in truck (i.e. 1 gal of gasoline displaces 1 gal of vapors in a truck).

Criteria Emissions from Pilot Light - PropanePilot Gas 21 SCFH Propane @ 4 PSIG - JZ Data

0.576 gal/hr Note: propane = 36.43 cf/gal

Pollutant Emission Factor (1) Emissions Emissions Emissions(lb/1000 gal) (lb/hr) (lb/yr) (tpy)

SO2(2) 0.018 0.00001 0.09 0.0000

NOx 14 0.0081 70.70 0.0353CO 1.9 0.0011 9.59 0.0048PM 0.4 0.0002 2.02 0.0010

PM-10 0.4 0.0002 2.02 0.0010PM-2.5 0.4 0.0002 2.02 0.0010

Pb none 0.0000 0.00 0.0000Notes:1) AP-42, Liquefied Petroleum Gas Combustion, Table 1.5-1; Commercial Boiler (between 0.3 and 10 MMBTU/hr).2) The SO2 factor assumes a sulfur content of 0.2 gr/100 cu.ft. of gas vapor.

Table 2. Loading Racks Potential Emission Calculations (2 pages)Newport Terminal

The flare is used as a control device to combust the vapor recovery system offgas from the No. 1 Loading Rack. It is assumed that 1.3% of vapors from truck loading will bypass the flare, uncontrolled. This factor accounts for VOC leaks from the truck trailer and vapor collection system during loading. Controlled VOC emissions from the flare are based on manufacturer's guarantee of 35 mg/L; uncontrolled VOC emissions from the loading rack are based on AP-42 equations, as calculated below. Because Newport is accepting a VOC emissions limit on the No. 1 Loading Rack to avoid major source status, a limitation on gasoline throughput is unnecessary. The pilot light on the flare uses propane for fuel. Total emissions from the flare include both the emissions from the gasoline vapor combustion and from the pilot light.

Although the flares are considered to be smokeless, the PM emission factors are based on the soot concentration for a lightly smoking flare.


VOC Emissions - Fuel Oil DispenserMaximum Throughput 600000 gal/yr equals 68.49 gal/hr

Maximum Annual

Throughput (gal/hr)VOC Emission Factor (mg/l)

VOC Emission Factor (lb/1000

gal)Emission Rate

(lbs/hr)

Emission Rate

(lbs/day)

Emission Rate

(lbs/yr)

Emission Rate (TPY)

Fuel Oil 68.5 na 0.0176 0.001 0.03 10.56 0.005

VOC Loading Loss emission factor for No. 1 Fuel Oil and gasoline is calculated as follows (based on AP 42 section 5.2):LL = 12.46 S*P*M/T

where: LL = Loading Loss (lb/1000 gal)

S = Saturation factor (see Table 5.2-1)P = True Vapor Pressure of Liquid Loaded (psia)M = Molecular Weight of Vapors (lb/lb-mole)T = Temperature of Bulk Liquid Loaded, deg. R (deg. F + 460)

No.1 Fuel Oil No. 2 Fuel Oil GasolineS 1.00 1.00 1.00P 0.0055 0.0042 5.34M 130 130 62

Ave. Temp deg. F 46.3 46.3 46.3LL 0.0176 0.0134 8.1479

Notes:Use No. 1 Fuel Oil for Loading Loss Factor at No. 2 Loading Rack since it is more conservative.Gasoling loading factor is used for flare emissions calculation. Gasoline properties are from TANKS 4.09 output.

Newport TerminalTable 2 (cont'd). Loading Racks Potential Emission Calculations (2 pages)


Summary of Flare Emissions

Holiday, Newport TerminalLOADING RACK 1 VOC SOx NOx CO PM PM-10 FormaldehydeVOC Emiss from 119,909.18 0.00Criteria Emiss from Comb of Gasoline included above 2,491.87 10,196.17 25,490.42 101.96 101.96Criteria Emissions from Pilot Light included above 0.09 70.70 9.59 2.02 2.02 Propane

Total (lb/yr) 119,909.18 2,491.96 10,266.86 25,500.02 103.98 103.98 0.00Total (Ton/yr) 59.95 1.25 5.13 12.75 0.05 0.05 0.00

Note:Refer to Flare Combustion Calculation spreadsheet.

Holiday Title V Application

900.00 gpm54,000.00 gph

1,296,000.00 gpday

10.19 lb/hr89,295.73 lb/yr @ 35 mg/l

44.65 ton/yr

Title V Permit Application450.00 gpm

27,000.00 gph648,000.00 gpday


TANK INFORMATION: TK 004 TK 005 TK 006 TK 007 TK 008 TK 009 TK 010 Notes

Tank 106 - Gasoline PTE







Tank Type IFR IFR IFR IFR IFR IFR IFRMonth July July July July July July July Assumes July

Number of Landing Events per Year - - - - - 1 1 Assumes 2 roof landing per year

nd Total No. of Days on its Legs w/no Refilling, days 2 2 2 2 2 2 2 Assumes 2 days on legs

D Tank Diameter, ft 67 100 100 100 100 100 100hd Height of the deck above the tank bottom, ft 5.00 5.00 5.00 5.00 5.00 5.00 5.00 Assumes 5 feet

hle Height of the liquid above the tank bottom, ft 0.08 0.08 0.08 0.08 0.08 0.08 0.08 Assumes 1 inch

hv Height of the vapor space, ft 4.92 4.92 4.92 4.92 4.92 4.92 4.92

STORED PRODUCT INFORMATION:Product Name: Gasoline Gasoline Gasoline Gasoline Gasoline Gasoline Gasoline

RVP Reid Vapor Pressure of Product, psia 13 13 13 13 13 13 13 Assumes RVP 13

SDS Stock Distillation Slope, Dimensionless 3.0 3.0 3.0 3.0 3.0 3.0 3.0 AP-42, Chapter 7.1 - Gasoline Table 7.1-4

Mv Vapor Molecular Weight, lb/lbmole 62.00 62.00 62.00 62.00 62.00 62.00 62.00 From TANKS emissions report

Wl Liquid Density, lb/gal 5.60 5.60 5.60 5.60 5.60 5.60 5.60 From TANKS emissions report

A Vapor Pressure Coefficient, dimensionless 11.64 11.64 11.64 11.64 11.64 11.64 11.64AP-42 Chapter 7.1 - Gasoline Figure 7.1-15, Ethanol Table 7.1-5

B Vapor Pressure Coefficient, dimensionless 5,044 5,044 5,044 5,044 5,044 5,044 5,044AP-42 Chapter 7.1 - Gasoline Figure 7.1-15, Ethanol Table 7.1-5

C Vapor Pressure Coefficient, dimensionless AP-42 Chapter 7.1 - Ethanol Table 7.1-5

PVA Vapor Pressure at Daily Ave. Surface Temp, psia 8.801 8.801 8.801 8.801 8.801 8.801 8.801AP-42, Chapter 7.1 - Gasoline Formula 1-12a, Ethanol Formula 1-12b

REFILLED PRODUCT INFORMATION:Product Name: Gasoline Gasoline Gasoline Gasoline Gasoline Gasoline Gasoline

RVP Reid Vapor Pressure of Product, psia 13 13 13 13 13 13 13 Assumes RVP 15

SDS Stock Distillation Slope, Dimensionless 3.0 3.0 3.0 3.0 3.0 3.0 3.0 AP-42, Chapter 7.1 - Gasoline Table 7.1-4

Mv Vapor Molecular Weight, lb/lbmole 62 62 62 62 62 62 62 From TANKS emissions report

Wl Liquid Density, lb/gal 5.60 5.60 5.60 5.60 5.60 5.60 5.60 From TANKS emissions report

A Vapor Pressure Coefficient, dimensionless 11.64 11.64 11.64 11.64 11.64 11.64 11.64AP-42 Chapter 7.1 - Gasoline Figure 7.1-15, Ethanol Table 7.1-5

B Vapor Pressure Coefficient, dimensionless 5,044 5,044 5,044 5,044 5,044 5,044 5,044AP-42 Chapter 7.1 - Gasoline Figure 7.1-15, Ethanol Table 7.1-5

C Vapor Pressure Coefficient, dimensionless AP-42 Chapter 7.1 - Ethanol Table 7.1-5

PVA refill Vapor Pressure at Daily Ave. Surface Temp, psia 6.94 6.94 6.94 6.94 6.94 6.94 6.94AP-42, Chapter 7.1 - Gasoline Formula 1-12a, Ethanol Formula 1-12b

Trefill Temperature of the Liquid Refilling, Degrees F 60 60 60 60 60 60 60 Assume refill product is at 60 oF

Trefill Temperature of the Liquid Refilling, Degrees R 519.60 519.60 519.60 519.60 519.60 519.60 519.60

METEOROLOGICAL INFORMATION:

T = TLA Average Temp of vapor and liquid below roof, R 532.65 532.65 532.65 532.65 532.65 532.65 532.65API Manual of Petroleum Measurement Standards Chapter 19, Section 2, Table 16 - White tanks

Delta Tv Daily Vapor Temperature Range, R 24.28 24.28 24.28 24.28 24.28 24.28 24.28TAA Daily Average Ambient Temperature, R 532.65 532.65 532.65 532.65 532.65 532.65 532.65

TAX Daily Maximum Average Ambient Temp, Degrees F 83.4 83.4 83.4 83.4 83.4 83.4 83.4 TANKS 4.09d Meteorological Data

TAN Daily Minimum Average Ambient Temp, Degrees F 62.7 62.7 62.7 62.7 62.7 62.7 62.7 TANKS 4.09d Meteorological Data

Delta TA Daily Ambient Temperature Range, R 20.7 20.7 20.7 20.7 20.7 20.7 20.7

TB Liquid Bulk Temperature, R 532.7 532.7 532.7 532.7 532.7 532.7 532.7Pa Atmospheric Pressure, Psia 14.3 14.3 14.3 14.3 14.3 14.3 14.3 TANKS 4.09d Meteorological Data

I Daily Total Solar Insulation Factor, BTU/ft2*d 1,970.0 1,970.0 1,970.0 1,970.0 1,970.0 1,970.0 1,970.0 TANKS 4.09d Meteorological Data

alpha Tank Paint Solar Absorptance, dimensionless 0.17 0.17 0.17 0.17 0.17 0.17 0.17 Tanks are White

STANDING LOSS CALCULATION:

LS Standing Loss, lb/day 196.55 437.84 437.84 437.84 437.84 437.84 437.84

KE Vapor space expansion factor, dimensionless 0.39 0.39 0.39 0.39 0.39 0.39 0.39

PVA True Vapor Pressure of the stock liquid, psia 8.80 8.80 8.80 8.80 8.80 8.80 8.80Vv Vapor Space Volume ft3 17,334 38,615 38,615 38,615 38,615 38,615 38,615R Ideal Gas Constant, psia*ft3/lbmole*R 10.73 10.73 10.73 10.73 10.73 10.73 10.73T = TLA Average Temp of vapor and liquid below roof, R 532.65 532.65 532.65 532.65 532.65 532.65 532.65Mv Vapor Molecular Weight, lb/lbmole 62.00 62.00 62.00 62.00 62.00 62.00 62.00Ks Vented vapor saturation factor, dimensionless (< Sat 0.30 0.30 0.30 0.30 0.30 0.30 0.30 Must be < Saturation factor, S

hv Height of Vapor Space under Floating Roof, ft 4.92 4.92 4.92 4.92 4.92 4.92 4.92P* Vapor pressure function 0.2345 0.2345 0.2345 0.2345 0.2345 0.2345 0.2345LS max Limit on standing losses 12,360 27,533 27,533 27,533 27,533 27,533 27,533

PRODUCT REFILLING LOSS CALCULATION:

LF refill Refilling Loss, lb 802.39 1,787.45 1,787.45 1,787.45 1,787.45 1,787.45 1,787.45

Prefill True Vapor Pressure Liquid Refilling, psia 6.94 6.94 6.94 6.94 6.94 6.94 6.94Vv Vapor Space Volume ft3 17,334 38,615 38,615 38,615 38,615 38,615 38,615hv Height of Vapor Space under Floating Roof, ft 4.92 4.92 4.92 4.92 4.92 4.92 4.92D Tank Diameter, ft 67 100 100 100 100 100 100R Ideal Gas Constant, psia*ft3/lbmole*R 10.731 10.731 10.731 10.731 10.731 10.731 10.731Trefill Temperature of the Liquid Refilling, Degrees R, (Assu 519.6 519.6 519.6 519.6 519.6 519.6 519.6Mv Vapor Molecular Weight, lb/lbmole 62 62 62 62 62 62 62S Saturation Factor, dimensionless 0.60 0.60 0.60 0.60 0.60 0.60 0.60

Summary of Losses

LS Standing Losses per episode, lb 393.09 875.68 875.68 875.68 875.68 875.68 875.68

LF Product Refilling Losses per episode, lb 802.39 1,787.45 1,787.45 1,787.45 1,787.45 1,787.45 1,787.45

LT Total Landing Loss per Year, lb 0.00 0.00 0.00 0.00 0.00 2,663.13 2,663.13Total Landing Loss per Year, ton 0.0000 0.0000 0.0000 0.0000 0.0000 1.3316 1.3316

Total Land Loss Emissions (lb/yr) 5,326 Total Land Loss Emissions (ton/yr) 2.66

Notes:

1) Tank roof landing emissions are conservatively estimated for tanks in natural gasoline service even though Tanks 3, 4, and 6 may be in denatured ethanol service.

Calculation Methods

Tank landing emissions calculated using AP-42, Fifth Edition, Volume I Chapter 7.1, November 2006

Base equations for the floating roof landing loss calculations:

Internal Floating Roof Tank

IFRT Standing Loss LSL = nd KE (PVA VV / R T) MV KS (Maximum standing loss can not exceed LS max = 5.9 D2 hle Wl)

IFRT Filling Loss LFL = (PVA refill VV / R Trefill) MV S

Updated based on MPCA Comments from 2-12-2013 e-mail to Bruce Anthony from Andrea Walkush. Only the note was added to provide additional explanation of the basis for IFR landing emissions; nocalculations were changed.

Table 3a. IFR Tank Roof Landing VOC Potential Emission CalculationsNewport Terminal

2) Two tank roof landings are assumed per year based on the fact that Holiday typically has only one shutdown per year, and on average, one roof landing is needed per year for internal tank inspections, which are required every 10 years per API inspection code. The two largest tanks are used to conservatively calculate landing losses.

EC Attachment

Page 12 of 30

Table 4. Fugitive Potential Emission Calculations for Valves, Flanges, Pump SealsNewport Terminal

Source Description

Total Source Count (1) (2) (6) Service (3)

VOC Emission

Factor (4)

(kg/hour/source)

VOC Emission Factor

(lb/day/source)

Emission Rate

(lbs/hr)

Emission Rate

(lbs/day)

Emission

Rate (5)

(lbs/yr)

Emission Rate (TPY)

Valves 178 Light Liquid 4.30E-05 0.00227 0.02 0.40 148 0.07Flanges 776 Light Liquid 8.00E-06 0.00042 0.01 0.33 120 0.06Pump Seals 21 Light Liquid 5.40E-04 0.02855 0.02 0.60 219 0.11

Total Fitting Loss Emissions = 0.056 0.24

Notes:

6) Descripti Size Total

Centrifugal Pump seals NA 2

Vacuum pump seals NA 2

Flange 3” 40Flange 6” 40

Butterfly Valve 6” 6Check Valve 4” 1

Butterfly Valve 3” 4Blower components estimated using P&ID and adding extras to be conservative.

Valves 15

Flanges 10

Example Calculation:

VOC Emission (lbs/day) = Source Count X Emission Factor (lbs/day/source), assuming 100% VOCs in source liquid.

(1) The source count represents pipeline valves, flanges and pump seals that are 3 inches and larger. Fugitive emissions from components less that 3 inches were assumed to be negligible.

(2) Counts based on a terminal of similar size and complexity (Koch Pipeline Company; Madison, Wisconsin terminal), and the loading rack modification project (12/2008)

(3) The light liquid factors were selected on the basis that the pump and valve factors were higher for light liquid than those for gas and therefore more conservative. The light liquid factor, although less than the gas factor, was selected for the flange fittings since these fittings occur simultaneously with the valves.

(4) The emission factors were taken from Table 2-3, Marketing Terminal Average Emission Factors in the Protocol for Equipment Leak Emission Estimates, USEPA Office of Air Quality Planning and Standards, November 1995 (EPA-453/R-95-017).5) The annual emission rate is calculated assuming 8760 hours/year.


The tanker trailers will be purged of VOC before being brought into a building for maintenance.

VOC Loading Loss emission factor for gasoline. Based on AP 42 section 5.2.LL = 12.46 S*P*M/T



S: 1.00P: 5.34 psiaM: 62 lb/lb-mol

Average T: 46.3 FLL: 8.1479 lb/1000 gal

Assume one 8500 gal tanker purged per month: 102000 gal/yrTotal Emissions: 831 lbs/yr

0.42 tons/yr

Notes:Gasoling loading factor is used for flare emissions calculation. Gasoline properties are from TANKS 4.09 output.

8500 gallons/trailer tank1 trailers/month

Table 5. Potential Emission Calculations For Tanker PurgingNewport Terminal

EC Attachment

Page 17 of 30

Tanks 4.09b Meteorological Database Information City: St. Paul, MN

TAX TAA TAN I

Month Avg Daily Max Temp

(Deg F)

Avg Daily Temp (Deg

F)

Avg Daily Min Temp

(Deg F)

Solar Insolation

Factor (Btu/sqft-day)

Average Wind Speed (mph)

January 19.9 11.15 2.4 464 10.5

February 26.4 17.45 8.5 764 10.5

March 37.5 29.15 20.8 1,103.00 11.4

April 56 46.00 36 1,441.00 12.3

May 69.4 58.50 47.6 1,737.00 11.2

June 78.5 68.10 57.7 1,927.00 10.5

July 83.4 73.05 62.7 1,970.00 9.4

August 80.9 70.60 60.3 1,687.00 9.2

September 71 60.60 50.2 1,254.00 9.9

October 59.7 49.55 39.4 860 10.5

November 41.1 33.20 25.3 480 10.9

December 11.7 19.20 26.7 353 10.4

52.96 44.71 36.47 1170.00000 10.56 CalculatedAnnual 59.73 39.48 1267.52009 9.77

Daily Average Ambient Temperature (F) 44.71Atmospheric Pressure - Pa (psia) 14.297

Data Source: Tanks 4.09d Meterological Data

TANK 107-112 - ETHANOL, FLOATING ROOFID MIX ID PRIMARY NAME MONTH CAS TANK_TYPUSER ID CITY STATE COMPANDESC MET CTYSAMB_T T_MIN T_MAX INSOL P_A S_LOSS W_LOSS RIM_LOSSWD_LOSSDECKF_LODECKS_LOMOLES L_WT_FRAV_WT_FRAL_MO_FRAV_MO_FRAMOLWT VP_MOLWL_DENS ALPHA ALPHA_2 ALS_TEMPMLS_TEM XLS_TEMPBULK_T A_VP M_VP X_VP DIAMETEREFF_DIAMHEIGHT_SHEIGHT_RHEIGHT_LHEIGHT_AVOLUME Q_NET TURNOVESHL COLSSHL_CON PT_COND RF_COLSHRF_COND RF_TYPE VP_RANG T_RANGE VT_RANG RF_OUT VS_OUT VS_VOL V_DENS BV_RANG K_E K_S K_N K_P M_KR M_P M_KC M_C VENT_P VENT_V C_SLOPE D_RADIUSNC FC M_FF SD KD N_FACT TANK_CO RIM_PRIMRIM_SEC M_KRA M_KRB FITTING M_V DECK_TYPDECK_CO DECK_SEADECK_SEACOL_NO COL_DIAMSELF_SUPUNDER HEATED

13 1 TRUE Gasoline (RJanuary Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 11.15 2.4 19.9 464 14.297 0 0 65.30143 7.702939 181.0482 114.2775 0 0 0 0 0 92 62 5.6 0.17 0.17 490.2494 486.5472 493.9515 504.4025 3.880247 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.078994 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RFebruary Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 17.45 8.5 26.4 764 14.297 0 0 70.60211 7.702939 195.7444 123.5537 0 0 0 0 0 92 62 5.6 0.17 0.17 493.4243 489.2931 497.5554 504.4025 4.145796 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.085406 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RMay Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 58.5 47.6 69.4 1737 14.297 0 0 114.2122 7.702939 316.6533 199.8714 0 0 0 0 0 92 62 5.6 0.17 0.17 512.793 506.802 518.784 504.4025 6.099306 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.13816 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RJune Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 68.1 57.7 78.5 1927 14.297 0 0 128.051 7.702939 355.0213 224.0892 0 0 0 0 0 92 62 5.6 0.17 0.17 517.2722 511.235 523.3093 504.4025 6.641532 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.1549 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RSeptember Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 60.6 50.2 71 1254 14.297 0 0 115.0119 7.702939 318.8704 201.2708 0 0 0 0 0 92 62 5.6 0.17 0.17 513.0683 507.8321 518.3046 504.4025 6.131584 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.139127 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (ROctober Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 49.55 39.4 59.7 860 14.297 0 0 100.4265 7.702939 278.4325 175.7464 0 0 0 0 0 92 62 5.6 0.17 0.17 507.6772 502.9998 512.3546 504.4025 5.523787 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.121484 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RMarch Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 29.15 20.8 37.5 1103 14.297 0 0 81.04205 7.702939 224.6891 141.8236 0 0 0 0 0 92 62 5.6 0.17 0.17 499.0275 494.709 503.3461 504.4025 4.649998 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.098035 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RApril Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 46 36 56 1441 14.297 0 0 98.48603 7.702939 273.0525 172.3506 0 0 0 0 0 92 62 5.6 0.17 0.17 506.8955 501.5807 512.2103 504.4025 5.439803 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.119136 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RJuly Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 73.05 62.7 83.4 1970 14.297 0 0 135.6817 7.702939 376.1774 237.4429 0 0 0 0 0 92 62 5.6 0.17 0.17 519.5079 513.4376 525.5782 504.4025 6.92615 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.164131 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RAugust Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 70.6 60.3 80.9 1687 14.297 0 0 130.6465 7.702939 362.2174 228.6313 0 0 0 0 0 92 62 5.6 0.17 0.17 518.0498 512.3343 523.7654 504.4025 6.739459 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.15804 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RNovember Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 33.2 25.3 41.1 480 14.297 0 0 82.95394 7.702939 229.9898 145.1694 0 0 0 0 0 92 62 5.6 0.17 0.17 499.9728 496.5576 503.388 504.4025 4.73971 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.100348 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE13 1 TRUE Gasoline (RDecember Internal FloTK 107-112NewportMinnesot Holiday Gasoline stSt. Paul, M 19.2 26.7 11.7 353 14.297 0 0 70.98157 7.702939 196.7964 124.2177 0 0 0 0 0 92 62 5.6 0.17 0.17 493.6423 495.9222 491.3623 504.4025 4.164555 0 0 100 0 0 0 0 0 2350231 3817078 19.48954 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.085865 1 0.0015 0 0 0 0 7 1 443.6 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 1570.795 7 1 FALSE FALSE FALSE

TANK 106 - GASOLINE, FLOATING ROOFID MIX ID PRIMARY NAME MONTH CAS TANK_TYPUSER ID CITY STATE COMPANDESC MET CTYSAMB_T T_MIN T_MAX INSOL P_A S_LOSS W_LOSS RIM_LOSSWD_LOSSDECKF_LODECKS_LOMOLES L_WT_FRAV_WT_FRAL_MO_FRAV_MO_FRAMOLWT VP_MOLWL_DENS ALPHA ALPHA_2 ALS_TEMPMLS_TEM XLS_TEMPBULK_T A_VP M_VP X_VP DIAMETEREFF_DIAMHEIGHT_SHEIGHT_RHEIGHT_LHEIGHT_AVOLUME Q_NET TURNOVESHL COLSSHL_CON PT_COND RF_COLSHRF_COND RF_TYPE VP_RANG T_RANGE VT_RANG RF_OUT VS_OUT VS_VOL V_DENS BV_RANG K_E K_S K_N K_P M_KR M_P M_KC M_C VENT_P VENT_V C_SLOPE D_RADIUSNC FC M_FF SD KD N_FACT TANK_CO RIM_PRIMRIM_SEC M_KRA M_KRB FITTING M_V DECK_TYPDECK_CO DECK_SEADECK_SEACOL_NO COL_DIAMSELF_SUPUNDER HEATED

8 1 TRUE Gasoline (RJanuary Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 11.15 2.4 19.9 464 14.297 0 0 43.75196 5.248472 141.1735 51.29917 0 0 0 0 0 92 62 5.6 0.17 0.17 490.2494 486.5472 493.9515 504.4025 3.880247 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.078994 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RFebruary Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 17.45 8.5 26.4 764 14.297 0 0 47.30342 5.248472 152.6329 55.46326 0 0 0 0 0 92 62 5.6 0.17 0.17 493.4243 489.2931 497.5554 504.4025 4.145796 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.085406 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RMarch Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 29.15 20.8 37.5 1103 14.297 0 0 54.29818 5.248472 175.2028 63.66461 0 0 0 0 0 92 62 5.6 0.17 0.17 499.0275 494.709 503.3461 504.4025 4.649998 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.098035 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RApril Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 46 36 56 1441 14.297 0 0 65.98564 5.248472 212.9145 77.36817 0 0 0 0 0 92 62 5.6 0.17 0.17 506.8955 501.5807 512.2103 504.4025 5.439803 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.119136 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RMay Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 58.5 47.6 69.4 1737 14.297 0 0 76.52218 5.248472 246.9125 89.72225 0 0 0 0 0 92 62 5.6 0.17 0.17 512.793 506.802 518.784 504.4025 6.099306 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.13816 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RJune Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 68.1 57.7 78.5 1927 14.297 0 0 85.79414 5.248472 276.8302 100.5936 0 0 0 0 0 92 62 5.6 0.17 0.17 517.2722 511.235 523.3093 504.4025 6.641532 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.1549 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RSeptember Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 60.6 50.2 71 1254 14.297 0 0 77.05795 5.248472 248.6413 90.35045 0 0 0 0 0 92 62 5.6 0.17 0.17 513.0683 507.8321 518.3046 504.4025 6.131584 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.139127 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (ROctober Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 49.55 39.4 59.7 860 14.297 0 0 67.28575 5.248472 217.1095 78.89255 0 0 0 0 0 92 62 5.6 0.17 0.17 507.6772 502.9998 512.3546 504.4025 5.523787 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.121484 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RJuly Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 73.05 62.7 83.4 1970 14.297 0 0 90.90672 5.248472 293.3268 106.5881 0 0 0 0 0 92 62 5.6 0.17 0.17 519.5079 513.4376 525.5782 504.4025 6.92615 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.164131 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RAugust Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 70.6 60.3 80.9 1687 14.297 0 0 87.53314 5.248472 282.4414 102.6326 0 0 0 0 0 92 62 5.6 0.17 0.17 518.0498 512.3343 523.7654 504.4025 6.739459 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.15804 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RNovember Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 33.2 25.3 41.1 480 14.297 0 0 55.57914 5.248472 179.3361 65.16654 0 0 0 0 0 92 62 5.6 0.17 0.17 499.9728 496.5576 503.388 504.4025 4.73971 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.100348 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE8 1 TRUE Gasoline (RDecember Internal FloTK106 NewportMinnesot Holiday Gasoline T St. Paul, M 19.2 26.7 11.7 353 14.297 0 0 47.55765 5.248472 153.4533 55.76135 0 0 0 0 0 92 62 5.6 0.17 0.17 493.6423 495.9222 491.3623 504.4025 4.164555 0 0 67 0 0 0 0 0 1081394 1735035 19.25332 White/Whit Light Rust Good White/Whit Good 0 0 0 0 0 0 0 0 0 0 0 0 1.6 0.085865 1 0.0015 0 0 0 0 5 1 345.9 0.2 0.14 1.5 Liquid-mouNone 1.6 0.3 Detail 0 Bolted Sheet Sheet: 5 Ft 705.1299 5 1 FALSE FALSE FALSE

Summary of Emission Changes for form CH-01Emissions (tpy)

Existing Proposed Difference Existing Proposed Difference Existing Proposed Difference Existing Proposed Difference Existing Proposed Difference Existing Proposed Difference Existing Proposed DifferenceSOx 1.25 0.12 -1.12 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 1 0 -1.12NOx 5 0.51 -4.62 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 5 1 -4.62CO 12.75 1.28 -11.48 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 13 1 -11.48PM 0.05 0.01 -0.05 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 0 0 -0.05

PM-10 0.05 0.01 -0.05 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 0 0 -0.05PM-2.5 0.05 0.01 -0.05 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 0 0 -0.05VOC 59.95 31.44 -28.52 0.20 0.24 0.04 31.80 31.80 0.00 2.66 2.66 0.00 0.01 0.01 0.00 0.42 0.42 0.00 95 67 -28.48

Total HAP 2.40 1.26 -1.14 0.02 0.03 0.00 0.89 0.89 0.00 0.11 0.11 0.00 0.00 0.00 0.00 0.02 0.02 0.00 3 2 -1.14

CO2 4018 401.83 -3,616 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 4,018 402 -3,616CH4 0.17 0.017 -0.15 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 0 0 -0.15N2O 0.03 0.0034 -0.03 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 0 0 -0.03

CO2-e 4,033 403.26 -3,629 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- 4,033 403 -3,629

Total FacilityEU 001 Fittings Tanks Tank Landings FO Dispenser Tanker Purging

Newport Terminal

Source SOx NOx CO PM PM-10 PM-2.5 VOC CO2 CH4 N2O CO2-e Pb Benzene Toluene Ethylbenzene Xylene o-Xylene n-HexaneIsopropylbenzene

2,2,4-Trimethylpentane Total HAP

lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr

TK012 No 1 & 2 FO (TK012) [Insignificant] 11 0.28 0.23 0.04 0.00 0.01 0.62 0.01 0.00 1.17TK013 Gasoline Additive (TK013) [Insignificant] 21 0.16 0.14 0.01 0.03 0.01 0.39 0.00 0.10 0.85TK001 Tank 103 Ethanol (TK001) 6,323 0 0 0 0 0 0 0 0 0TK002 Tank 104 Ethanol (TK002) 6,323 0 0 0 0 0 0 0 0 0TK003 Tank 105 Ethanol (TK003) 6,323 0 0 0 0 0 0 0 0 0TK004 Tank 106 Gasoline (TK004) 4,386 34 29 2 7 2 81 0 21 175TK005 Tank 107 Gasoline (TK005) 6,718 52 44 3 10 3 124 0 33 269TK006 Tank 108 Gasoline (TK006) 6,718 52 44 3 10 3 124 0 33 269TK007 Tank 109 Gasoline (TK007) 6,718 52 44 3 10 3 124 0 33 269TK008 Tank 110 Gasoline (TK008) 6,718 52 44 3 10 3 124 0 33 269TK009 Tank 111 Gasoline (TK009) 6,616 51 44 3 10 3 122 0 32 265TK010 Tank 112 Gasoline (TK010) 6,718 52 44 3 10 3 124 0 33 269

IFR Tank Roof LandingsTanks 106-112 Gasoline 5,326 41 35 2 8 3 98 0 26 213Tank 106 Gasoline 0Tank 107 Gasoline 0Tank 108 Gasoline 0Tank 109 Gasoline 0Tank 110 Gasoline 0Tank 111 Gasoline 2,663Tank 112 Gasoline 2,663

EU001 Loading Rack 1Gasoline Vapor Combustion at VRU 249 1,020 2,549 10 10 10 62,874 803,663 34.33 6.87 806,513 --- 484 415 25 94 31 1,157 0 308 2,515Pilot Gas (propane) 0.01 7 1 0 0 0 incl. above 3.11 0.00 0.00 3.13 0 incl. above incl. above incl. above incl. above incl. above incl. above incl. above incl. above incl. above

249 1,027 2,550 10 10 10 62,874 803,666 34.33 6.87 806,516 0.00 484.13 414.97 25.15 94.31 31.44 1,156.87 0.00 308.08 2,514.94

Fuel Oil DispenserFuel Oil Loading [Insignificant] 10.56 0.27 0.22 0.03 0.00 0.01 0.59 0.01 0.01 1.14

Fugitive ComponentsFittings [Insignificant] 486 12.50 10.02 1.56 0.73 0.63 27.28 0.24 2.38 55.34

Tanker Purging 831 6 5 0 1 0 15 0 4 33

TOTAL (lb/yr) 249 1,027 2,550 10 10 10 133,119 803,666 34 7 806,516 0 888 761 47 171 57 2,120 0 559 4,603TOTAL (tons/yr) 0.12 0.51 1.28 0.01 0.01 0.01 66.56 402 0.02 0.00 403 0 0.44 0.38 0.02 0.09 0.03 1.06 0.00 0.28 2.30

Facility Projected Actual Emission Summary with New VRU in Service (in pounds per year unless otherwise specified in the table)



Newport Terminal

Source SOx NOx CO PM PM-10 PM-2.5 VOC CO2 CH4 N2O CO2-e Pb Benzene Toluene Ethylbenzene Xylene o-Xylene n-HexaneIsopropylbenzene

2,2,4-Trimethylpentane Total HAP

lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr lb/yr

TK012 No 1 & 2 FO (TK012) [Insignificant] 11 0.28 0.23 0.04 0.00 0.01 0.62 0.01 0.00 1.17TK013 Gasoline Additive (TK013) [Insignificant] 21 0.16 0.14 0.01 0.03 0.01 0.39 0.00 0.10 0.85TK001 Tank 103 Ethanol (TK001) 6,323 0 0 0 0 0 0 0 0 0TK002 Tank 104 Ethanol (TK002) 6,323 0 0 0 0 0 0 0 0 0TK003 Tank 105 Ethanol (TK003) 6,323 0 0 0 0 0 0 0 0 0TK004 Tank 106 Gasoline (TK004) 4,386 34 29 2 7 2 81 0 21 175TK005 Tank 107 Gasoline (TK005) 6,718 52 44 3 10 3 124 0 33 269TK006 Tank 108 Gasoline (TK006) 6,718 52 44 3 10 3 124 0 33 269TK007 Tank 109 Gasoline (TK007) 6,718 52 44 3 10 3 124 0 33 269TK008 Tank 110 Gasoline (TK008) 6,718 52 44 3 10 3 124 0 33 269TK009 Tank 111 Gasoline (TK009) 6,616 51 44 3 10 3 122 0 32 265TK010 Tank 112 Gasoline (TK010) 6,718 52 44 3 10 3 124 0 33 269

IFR Tank Roof LandingsTanks 106-112 Gasoline 5,326 41 35 2 8 3 98 0 26 213Tank 106 Gasoline 0Tank 107 Gasoline 0Tank 108 Gasoline 0Tank 109 Gasoline 0Tank 110 Gasoline 0Tank 111 Gasoline 2,663Tank 112 Gasoline 2,663

EU001 Loading Rack 1Gasoline Vapor Combustion at Flare 2,492 10,196 25,490 102 102 102 119,909 8,036,630 343 69 8,065,128 --- 923 791 48 180 60 2,206 0 588 4,796Pilot Gas (propane) 0.09 71 10 2 2 2 incl. above 31 1.52E-03 3.04E-04 31 0 incl. above incl. above incl. above incl. above incl. above incl. above incl. above incl. above incl. above

2,492 10,267 25,500 104 104 104 119,909 8,036,661 343.35 69 8,065,159 0.00 923.30 791.40 47.96 179.86 59.95 2,206.33 0.00 587.55 4,796.37

Fuel Oil DispenserFuel Oil Loading [Insignificant] 10.56 0.27 0.22 0.03 0.00 0.01 0.59 0.01 0.01 1.14

Fugitive ComponentsFittings [Insignificant] 409 10.51 8.43 1.31 0.61 0.53 22.95 0.20 2.00 46.56

Tanker Purging 831 6 5 0 1 0 15 0 4 33

TOTAL (lb/yr) 2,492 10,267 25,500 104 104 104 190,078 8,036,661 343 69 8,065,159 0 1,325 1,135 70 257 86 3,165 0 838 6,876TOTAL (tons/yr) 1.25 5.13 12.75 0.05 0.05 0.05 95.04 4,018 0.17 0.03 4,033 0 0.66 0.57 0.03 0.13 0.04 1.58 0.00 0.42 3.44

Existing Facility Projected Actual Emission Summary (in pounds per year unless otherwise specified in the table)



New VRU Fugitive Potential Emission Calculations for Valves, Flanges, Pump SealsNewport Terminal

Source Description

Total Source Count Service (3)

VOC Emission

Factor (4)

(kg/hour/source)

VOC Emission Factor

(lb/day/source)

Emission Rate

(lbs/hr)

Emission Rate

(lbs/day)

Emission

Rate (5)

(lbs/yr)

Emission Rate (TPY)

Valves 26 Light Liquid 4.30E-05 0.00227 0.002 0.06 22 0.01Flanges 90 Light Liquid 8.00E-06 0.00042 0.002 0.04 14 0.01Pump Seals 4 Light Liquid 5.40E-04 0.02855 0.005 0.11 42 0.02

Totals = 0.009 0.04

Notes:

6) Description Size Total

Centrifugal Pump seals NA 2

Vacuum pump seals NA 2

Flange 1” 10

Flange 1 ½” 1Flange 3” 40Flange 6” 40

Butterfly Valve 6” 6Check Valve 4” 1

Butterfly Valve 3” 4Globe Valve 1” 6

Blower components estimated using P&ID and adding extras to be conservative. Valves 15

Flanges 10

Example Calculation:

VOC Emission (lbs/day) = Source Count X Emission Factor (lbs/day/source), assuming 100% VOCs in source liquid.

(1) The source count represents pipeline valves, flanges and pump seals that are 3 inches and larger. Fugitive emissions from components less that 3 inches were assumed to be negligible.

(2) Counts based on a terminal of similar size and complexity (Koch Pipeline Company; Madison, Wisconsin terminal), and the loading rack modification project (12/2008)

(3) The light liquid factors were selected on the basis that the pump and valve factors were higher for light liquid than those for gas and therefore more conservative. The light liquid factor, although less than the gas factor, was selected for the flange fittings since these fittings occur simultaneously with the valves.

(4) The emission factors were taken from Table 2-3, Marketing Terminal Average Emission Factors in the Protocol for Equipment Leak Emission Estimates, USEPA Office of Air Quality Planning and Standards, November 1995 (EPA-453/R-95-017).5) The annual emission rate is calculated assuming 8760 hours/year.


VOC Emissions from Gasoline Vapors - No. 1 Loading Rack NotesMaximum Physical Throughput Capacity (gal/day): 1,795,200 Basis: four 8500-gal trucks loaded per 30 min for

24 hours with a 10% safety factor.Maximum Annual Throughput (gal/yr): 655,248,000 Assumes year-round operation at maximum throughput.Projected Annual Throughput (gal/yr): 305,750,362 Assumes 2006 throughput plus a 33% increase.

Estimated Uptime of VRU: 90%Estimated Uptime of Flare: 10%

Loading Rack Operation

Maximum Annual

Throughput (gal/yr)Vapor Collection

Efficiency (%)VOC Emission Factor (mg/L)

Factor (lb/1000 gal)

Emission Rate (lb/yr)

Emission Rate (tpy)

Controlled by Flare 30,177,561 98.7 35 0.29 8,751 4.38Controlled by VRU 271,598,046 98.7 10 0.08 21,728 10.86Uncontrolled 3,974,755 --- n/a 8.15 32,394 16.20

Total VOC Emissions: 62,874 31.44

Criteria Pollutant Emissions from Combustion of Gasoline VaporsAssume VRU uptime is 90%, flare used as back-up for remaining 10%. Combustion emissions are from the flare only.

Loading Rack Throughput with Flare Usage: 30,575,036 gal/yr115,726,512 liter/yr

Loading Rack Loss: 8.15 lb/1000 gal (See calculation on next page.)Maximum Combusted Gasoline Vapors: 249,187 lb/yr

Pollutant Emissions EmissionsEmission Factor (lb/yr) (TPY)

SO2 500 ppmw (1) 249.19 0.12NOx 4 mg/l (2) 1,019.62 0.51CO 10 mg/l (2) 2,549.04 1.27PM 40 ug/l (3) 10.20 0.01

PM-10 40 ug/l (3) 10.20 0.01PM-2.5 40 ug/l (3) 10.20 0.01

Notes:(1) Use 500 ppmw sulfur in gasoline for SO2 emissions.(2) Manufacturer's guaranteed emissions level(3) Emission Factors from AP-42, Table 13.5-1, Industrial Flare Operations.Assumes throughput displaces equivalent amount of vapors in truck (i.e. 1 gal of gasoline displaces 1 gal of vapors in a truck).

Criteria Emissions from Pilot Light - PropaneFlare pilot is only lit during flare operation (10% uptime)

Pilot Gas 21 SCFH Propane @ 4 PSIG - JZ Data0.576 gal/hr Note: propane = 36.43 cf/gal

876 hr/yr

Pollutant Emission Factor (1) Emissions Emissions Emissions(lb/1000 gal) (lb/hr) (lb/yr) (tpy)

SO2(2) 0.018 0.00001 0.01 0.0000

NOx 14 0.0081 7.07 0.0035CO 1.9 0.0011 0.96 0.0005PM 0.4 0.0002 0.20 0.0001

PM-10 0.4 0.0002 0.20 0.0001PM-2.5 0.4 0.0002 0.20 0.0001

Pb none 0.0000 0.00 0.0000Notes:1) AP-42, Liquefied Petroleum Gas Combustion, Table 1.5-1; Commercial Boiler (between 0.3 and 10 MMBTU/hr).2) The SO2 factor assumes a sulfur content of 0.2 gr/100 cu.ft. of gas vapor.

Loading Racks with New VRU In Service - Potential Emission Calculations (2 pages)Newport Terminal

The flare is used as a control device to combust the vapor recovery system offgas from the No. 1 Loading Rack. It is assumed that 1.3% of vapors from truck loading will bypass the flare, uncontrolled. This factor accounts for VOC leaks from the truck trailer and vapor collection system during loading. Controlled VOC emissions from the flare are based on manufacturer's guarantee of 35 mg/L; uncontrolled VOC emissions from the loading rack are based on AP-42 equations, as calculated below. Because Newport is accepting a VOC emissions limit on the No. 1 Loading Rack to avoid major source status, a limitation on gasoline throughput is unnecessary. The pilot light on the flare uses propane for fuel. Total emissions from the flare include both the emissions from the gasoline vapor combustion and from the pilot light.

Although the flares are considered to be smokeless, the PM emission factors are based on the soot concentration for a lightly smoking flare.


VOC Emissions - Fuel Oil DispenserMaximum Throughput 600000 gal/yr equals 68.49 gal/hr

Maximum Annual

Throughput (gal/hr)VOC Emission Factor (mg/l)

VOC Emission Factor (lb/1000

gal)Emission Rate

(lbs/hr)

Emission Rate

(lbs/day)

Emission Rate

(lbs/yr)

Emission Rate (TPY)

Fuel Oil 68.5 na 0.0176 0.001 0.03 10.56 0.005

VOC Loading Loss emission factor for No. 1 Fuel Oil and gasoline is calculated as follows (based on AP 42 section 5.2):LL = 12.46 S*P*M/T



No.1 Fuel Oil No. 2 Fuel Oil GasolineS 1.00 1.00 1.00P 0.0055 0.0042 5.34M 130 130 62

Ave. Temp deg. F 46.3 46.3 46.3LL 0.0176 0.0134 8.1479

Notes:Use No. 1 Fuel Oil for Loading Loss Factor at No. 2 Loading Rack since it is more conservative.Gasoling loading factor is used for flare emissions calculation. Gasoline properties are from TANKS 4.09 output.

Newport TerminalTable 2 (cont'd). Loading Racks Potential Emission Calculations (2 pages)


Summary of Flare Emissions

Holiday, Newport TerminalLOADING RACK 1 VOC SOx NOx CO PM PM-10 FormaldehydeVOC Emiss from Comb 62,873.59 0.00Criteria Emiss from Comb of Gasoline included above 249.19 1,019.62 2,549.04 10.20 10.20Pilot Light included above 0.01 7.07 0.96 0.20 0.20 Propane

Total (lb/yr) 62,873.59 249.20 1,026.69 2,550.00 10.40 10.40 0.00Total (Ton/yr) 31.44 0.12 0.51 1.28 0.01 0.01 0.00

Note:Refer to Flare Combustion Calculation spreadsheet.

Holiday Title V Application

900.00 gpm54,000.00 gph

1,296,000.00 gpday

1.02 lb/hr8,929.57 lb/yr @ 35 mg/l

4.46 ton/yr

Title V Permit Application450.00 gpm

27,000.00 gph648,000.00 gpday


All GHG emissions are from combustion at the flare. There are no GHG emissions associated with the VRU.

Gasoline CombustionPotential Gasoline Vapors Combusted at

Loading Rack: 249,187 lb/yr gasoline vaporsDensity of gasoline: 6 lb/gal

Gasoline Vapors Combusted: 41,531 gal/yrPropane Combusted

Flare pilot gas flow: 0.58 gal/hrFlare pilot hours of operation: 876 hr/yr

Propane Combusted: 505 gal/yr

Diesel CombustedDiesel fuel flow @ 100% load: 31.9 gal/hr

Engine hours of operation: 90 hr/yrDiesel Combusted: 2,871 gal/yr

PollutantHHV

(MMBtu/gal)

Emission Factor

(kg CO2/MMBtu)

Potential Emissions

(kg/yr)

Potential Emissions

(tpy)CO2e GWP

Existing Potential Emissions CO2e

(tpy)

Future Potential Emissions CO2e

(tpy)

Gasoline CO2 0.125 70.22 364,539 402 1 402 402CH4 0.125 3.0E-03 16 0.02 21 0 0.4N2O 0.125 6.0E-04 3 0.00 310 1 1

PropaneCO2 0.091 61.46 1 0.00 1 0.00 0.00CH4 0.091 3.0E-03 6.9E-05 7.6E-08 21 1.6E-06 1.6E-06N2O 0.091 6.0E-04 1.4E-05 1.5E-08 310 4.7E-06 4.7E-06

DieselCO2 0.138 73.96 29,303 32.3 1 32.3CH4 0.138 3.0E-03 1 1.3E-03 21 2.8E-02N2O 0.138 6.0E-04 0 2.6E-04 310 8.1E-02

TotalCO2 402 1 402 434CH4 0.02 21 0 0N2O 0.00 310 1 1

403 436

Table 7. Potential GHG Emission Calculations Newport Terminal


Attachment 2: Facility Description and CD‐01 Forms

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

Show:

Action:

AQD Facility ID:

Facility Name:

Active and Pending Records

PER 005

16300010

Newport Terminal Corp

FACILITY DESCRIPTION: GROUPS (GP)

4 March, 2013 11:10

ID No. AddedBy

(Action)

RetiredBy

(Action)

Includein EI

OperatorID

for Item

Group Description Group ItemsGroupStatus

1 GP 001 PER 002 Storage Tanks TK 001, TK 002, TK 003, TK 004, TK 005, TK 006, TK 007, TK 008, TK 009, TK010, TK 012, TK 013

Active

2 GP 002 PER 004 40 CFR pt. 63, subp. BBBBBB Requirements, Enforcement Not Delegated toMPCA.

CE 001, CE 002, EU 001, MR 001, MR 002, TK 004, TK 005, TK 006, TK 007,TK 008, TK 009, TK 010

Active

Page 1 of 1

Insignif-icant

Activity

OperatorID

for Item


Show: Active and Pending Records

Action: PER 005

AQD Facility ID: 16300010

Facility Name: Newport Terminal Corp

4 March, 2013 11:17

FACILITY DESCRIPTION: STORAGE TANKS (TK)

ID No. Capacity(1000 gal)

InteriorHeight

(ft.)

InteriorDiameter

(ft.)

AddedBy

(Action)

Construction TypeTankStatus

Product StoredControlEquip.

ID No(s).

RetiredBy

(Action)

1031 TK 001 50037 Fixed RoofActive PER 002 Tank 103 Ethanol



1064 TK 004 108141 Internal Floating RoofActive PER 002 Tank 106 Gasoline







A11 TK 011 1720 Fixed RoofRemoved PER 002 Gasoline

Tank B12 TK 012 1720 12 Fixed RoofActive PER 002 Diesel Fuel

Tank C13 TK 013 1225 9 Fixed RoofActive PER 002 Gasoline additive

Page 1 of 1 (a)

ID No.

FACILITY DESCRIPTION: STORAGE TANKS (TK)

4 March, 2013 11:17

YearRemoved

YearInstalled

Seal Type(floating roof only)

AddedBy

(Action)

Support Type(floating roof only)

ColumnCount

ColumnDiameter

(ft.)

Deck Type(floating roof only)

TankStatus

1 TK 001 1959PER 002Active



4 TK 004 1963Resilient seal (nonmetallic), liquid mounted, pPER 002 Column Supported Roof, Construction Type N 5 1 WeldedActive







11 TK 011 1964PER 002Removed



Page 1 of 1 (b)



Action: PER 005



4 March, 2013 11:16

FACILITY DESCRIPTION: FUGITIVE SOURCES (FS)

ID No. Fugitive Source Description YearInstalled

YearRemoved

AddedBy

(Action)

RetiredBy

(Action)

Insignif-icant

Activity

OperatorID

for Item

Pollutant(s)Emitted

ControlEquip.

ID No(s).

FugitiveSourceStatus

1 FS 001 PER 002 VOCHAPorg

Valves, Flanges, & SealsActive

2 FS 002 PER 002 HAPorgVOC

Tanker PurgingActive

Page 1 of 1



Action: PER 005



4 March, 2013 11:15

FACILITY DESCRIPTION: STACK/VENTS (SV)

ID No. Discharge DirectionFlow Rate/Temperature

Information Source

Exit GasTemperature

at Top(ºF)

DesignFlow Rate

at Top(ACFM)

Width(feet)

Diameteror Length

(feet)

Inside DimensionsHeight ofOpening

FromGround(feet)

AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item

Operators DescriptionStack/Vent

Status

1 SV 001 Up, No CapEstimate701200.540PER 002 Loading Rack 1 - gasolineActive

2 SV 002 Up, No CapEstimate706020PER 002 Loading Rack 2 - diesel fuel and ethanol loadingActive

3 SV 003 HorizontalManufacturer903540.513.7PER 004 VRUActive

4 SV 004 Up, No CapTest801500.510PER 005 Soil Vapor Extraction SkidActive

5 SV 005 Up, No CapManufacturer908.3658.6.679.2PER 005 Emergency Diesel GeneratorActive

Page 1 of 1



Action: PER 005



4 March, 2013 11:17

FACILITY DESCRIPTION: CONTROL EQUIPMENT (CE)

ID No. AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item

Control

Equip.Type

Control Equipment Description ModelControlEquip.Status

Manufacturer PollutantsControlled

AfterburnerCombustionParameters

CaptureEfficiency

(%)

Destruction/CollectionEfficiency

(%)

1 CE 001 PER 004 023 Flaring ZFT-2-6-35-X-2/6Active John Zink HAPorgVOC

98.798.7

96.496.4

2 CE 002 PER 004 047 Vapor Recovery System-Condensers, Hoods, & OtherEnclosures

JT-7051-1000DActive Jordan Technologies VOC 100 99

Page 1 of 1

ST. PAUL, MN 55155-4194


Action: PER 005


Facility Name:

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD

4 March, 2013 11:19

FACILITY DESCRIPTION: EMISSION UNIT (EU)

MaxFuelInput

(mil Btu)


RetiredBy

(Action)

Operator DescriptionID No. EmissionUnit

Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity

SICManufacturer ModelNumber

Max.Design

Capacity

MaximumDesign

Capacity

Materials Units n Units d

1 Loading Rack 1 - gasolineEU 001 Active PER 004 CE 001CE 002

SV 001 (B)SV 003 (M)

Min 5171Emco-Wheaton NA 2400 Gal

2 Loading Rack 2 - diesel fueland loading

EU 002 Active PER 002 SV 002 (M) Min 5171Emoc-Wheaton NA 450 Gal

3 Loading Rack 2 - diesel fueland loading

EU 002 Active PER 005 SV 002 (M) Min 5171Emoc-Wheaton NA 450 Gal

4 Soil Vapor ExtractionEquipment

EU 003 Active PER 005 SV 004 (M) Min 5171Custom NA 300 Ft3

4.335 Diesel emergency generatorEU 004 Active PER 005 SV 005 (M) Elect Energy5171Caterpiller C15 S/N C5E03760 619 Hp

Page 1 of 1 (a)

4 March, 2013 11:19

FACILITY DESCRIPTION: EMISSION UNIT (EU)

ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat

Firing MethodAddedBy

(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

1 EU 001 PER 004 10/15/200810/15/2008Active

2 EU 002 PER 002 12/31/197312/31/1973Active

3 EU 002 PER 005 12/31/197312/31/1973Active

4 EU 003 PER 005 01/28/201307/01/200306/23/2003Active

5 EU 004 PER 005Active

Page 1 of 1 (b)


4 March, 2013 11:18

FACILITY DESCRIPTION: Potential-to-emit (by item)


AQD Facility ID:

Facility Name:

16300010


Item UnrestrictedPotential

(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 001

Benzene PER 002

Carbon Monoxide PER 001 1.37E+01 2.00E+003.13E+00 1.37E+01

Ethylbenzene PER 002

Hexane PER 002

HAPs - Total PER 002

Phenol PER 002

Toluene PER 002

Xylenes (mixed isomers) PER 002

Nitrogen Oxides PER 001 5.51E+00 1.00E+001.26E+00 5.51E+00

PM < 10 micron PER 001 5.60E-02 1.00E-021.30E-02 5.60E-02

Total Particulate Matter PER 001 5.60E-02 1.00E-021.30E-02 5.60E-02

Sulfur Dioxide PER 001 8.00E-01 2.00E-011.80E-01 8.00E-01

Volatile Organic Compounds PER 002 5.50E+012.95E+01 1.29E+02

EU 004

Acetaldehyde PER 005 4.91E-061.09E-04 2.73E-05

Acrolein PER 005 1.54E-063.41E-05 8.54E-06

Benzene PER 005 1.51E-043.36E-03 8.41E-04

1,3-Butadiene PER 005 7.62E-061.69E-04 4.24E-05

Carbon Dioxide Equivalent PER 005 3.20E+017.39E+00 1.80E+02

Carbon Monoxide PER 005 2.15E-024.78E-01 1.19E-01

Formaldehyde PER 005 1.54E-053.42E-04 8.55E-05

Naphthalene PER 005 2.53E-055.63E-04 1.41E-04

HAPs - Total PER 005 4.59E-047.34E-03 1.84E-03

Toluene PER 005 5.48E-051.22E-03 3.04E-04

Xylenes (mixed isomers) PER 005 3.76E-058.36E-04 2.09E-04

Nitrogen Oxides PER 005 2.20E-014.82E+00 1.20E+00

PM < 2.5 micron PER 005 3.58E-037.96E-02 1.99E-02

PM < 10 micron PER 005 3.58E-037.96E-02 1.99E-02

Polycyclic organic matter PER 005 1.59E-053.53E-04 8.83E-05

Total Particulate Matter PER 005 3.58E-037.96E-02 1.99E-02

Sulfur Dioxide PER 005 2.95E-042.17E+00 5.42E-01

Volatile Organic Compounds PER 005 1.75E-023.90E-01 9.75E-02

FC 000

Benzene PER 002 7.30E-011.18E+00

Benzene PER 005 6.60E-011.18E+00

Ethylbenzene PER 002 4.00E-026.00E-02


Hexane PER 002 1.76E+002.81E+00

Hexane PER 005 1.58E+002.81E+00

Toluene PER 002 6.30E-011.01E+00

Toluene PER 005 5.70E-011.01E+00

Xylenes (mixed isomers) PER 002 1.40E-012.30E-01

Xylenes (mixed isomers) PER 005 1.30E-012.30E-01

2,2,4-trimethylpentane PER 002 4.70E-017.50E-01

2,2,4-trimethylpentane PER 005 4.20E-017.50E-01

o-Xylenes PER 002 5.00E-028.00E-02

Page 1 of 3


4 March, 2013 11:18



AQD Facility ID:

Facility Name:

16300010



(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

FC 000

o-Xylenes PER 005 4.00E-028.00E-02

Volatile Organic Compounds PER 002 9.50E+011.52E+02

FS 001

Volatile Organic Compounds PER 002 4.00E-02 1.80E-01

FS 002

Volatile Organic Compounds PER 002 4.20E-01

TK 001


TK 002


TK 003


TK 004

Benzene PER 001 1.00E-02 1.00E-032.00E-03 1.00E-02

Ethylbenzene PER 001

Hexane PER 001 2.60E-02 1.00E-036.00E-03 2.60E-02

HAPs - Total PER 001 4.80E-02 1.00E-031.00E-02 4.80E-02

Phenol PER 001

Toluene PER 001 1.00E-02 1.00E-032.00E-03 1.00E-02


Volatile Organic Compounds PER 002 5.00E-012.20E+00

TK 005

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



TK 006

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



TK 007

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Page 2 of 3


4 March, 2013 11:18



AQD Facility ID:

Facility Name:

16300010



(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

TK 007

Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



TK 008

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



TK 009

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



TK 010

Benzene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02


Hexane PER 001 3.60E-02 1.00E-038.00E-03 3.60E-02


Phenol PER 001 1.00E-031.00E-03

Toluene PER 001 1.50E-02 1.00E-033.00E-03 1.50E-02



Page 3 of 3

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY

4 March, 2013 11:18

520 LAFAYETTE ROADST. PAUL, MN 55155-4194 FACILITY DESCRIPTION: DATA ACQUISITION SYSTEMS (DA)


Action: PER 005



ID No. RemovalDate

InstallationDate

Data StorageMedium

Serial NumberManufacturer Model NumberDASStatus

OperatorID

for Item

Data Acquisition System DescriptionRetiredBy

(Action)

AddedBy

(Action)

1 DA 001 ElectronicS5H108847Yikagawa CX106-1-2 Style S4Active Pilot Flame UV Light SignalPER 004

2 DA 002 ElectronicTBDWonderware Intouch SCA TBDActive VRU CEMs Data AquisitionPER 004

Page 1 of 1



Action: PER 005



4 March, 2013 11:17

FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)

ParametersMonitored

Serial NumberID No. Model NumberManufacturerOperatorID

for Item

MonitoredItem

(ID No(s).)

RetiredBy

(Action)

AddedBy

(Action)

Monitor DescriptionMonitorStatus

1 TempMR 001 CE 001EU 001

PER 004 Temperature readingActive

2 VOC111022MR 002 JSGD11RJordan TechnologiesCE 002EU 001

PER 004 VRU CEMS, NDIR Gas AnalyzerActive

Page 1 of 1 (a)

4 March, 2013 11:17

FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)

ID No. AddedBy

(Action)

SpanValue

SystemFull-

ScaleValue

BypassCapa-bility?

RemovalDate

InstallationDate

OpticalPath

LengthRatio

MonitorStatus

1 MR 001 PER 004 11/01/2001Active

2 MR 002 PER 004 NoActive

Page 1 of 1 (b)

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01


Permit Number: 16300010 - 005

22 May, 2013 16:18Page 1 of 28

Subject Item: Total Facility

NC/CA

Type Citation Requirement

CD hdr SOURCE-SPECIFIC REQUIREMENTS1.0

CD 40 CFR Section 60.7(b); Minn. R.7019.0100, subp. 1

Recordkeeping: Maintain records of the occurrence and duration of any startup,shutdown, or malfunction in the operation of the facility including any malfunction ofthe air pollution control equipment or any periods during which a continuousmonitoring system or monitoring device is inoperative.

2.0

CD 40 CFR Section 60.503(c)(3);Minn. R. 7007.0800, subp. 2

Permit Appendices: This permit contains Appendices I and II as listed in the permitTable of Contents. The Permittee shall comply with all requirements contained inthe appendices.

3.0

CD hdr TOTAL FACILITY VOC LIMIT4.0

LIMIT Title I Condition: to avoidclassification as a major sourceunder 40 CFR Section 52.21 andMinn. R. 7007.3000; To avoidclassification as a major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200; To avoidmajor source classification under40 CFR Section 63.2

Volatile Organic Compounds: less than or equal to 95.0 tons/year using 12-monthRolling Sum calculated by the 15th day of each month for the previous 12-monthperiod using the calculation method below. This limit applies to the total VOCemissions from the facility.

5.0

CD hdr OPERATIONAL REQUIREMENTS6.0

CD Minn. Stat. Section 116.07, subds.4a & 9; Minn. R. 7007.0100, subp.7(A), 7(L), & 7(M); Minn. R.7007.0800, subps. 1, 2 & 4; Minn.R. 7009.0010-7009.0080

The Permittee shall comply with National Primary and Secondary Ambient AirQuality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air QualityStandards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstratedupon written request by the MPCA.

7.0

CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.

8.0

CD 40 CFR Section 63.11085(a);Minn. R. 7007.0800, subp. 2;Minn. R. 7007.0800, subp. 16(J)

Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated, unlessotherwise noted in Table A.

9.0

CD Minn. R. 7007.0800, subp. 14 and16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation.

10.0

CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.

11.0

CD Minn. R. 7011.0150 Fugitive Emissions: Do not cause or permit the handling, use, transporting, orstorage of any material in a manner which may allow avoidable amounts ofparticulate matter to become airborne. Comply with all other requirements listed inMinn. R. 7011.0150.

12.0

CD Minn. R. 7030.0010 - 7030.0080 Noise: The Permittee shall comply with the noise standards set forth in Minn. R.7030.0010 to 7030.0080 at all times during the operation of any emission units.This is a state only requirement and is not enforceable by the EPA Administrator orcitizens under the Clean Air Act.

13.0

CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).

14.0

CD Minn. R. 7007.0800, subp. 16 The Permittee shall comply with the General Conditions listed in Minn. R.7007.0800, subp. 16.

15.0

CD hdr PERFORMANCE TESTING16.0




22 May, 2013 16:18Page 2 of 28

CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, B, and/or C.

17.0

CD Minn. R. 7017.2018; Minn. R.7017.2030, subps. 1-4, Minn. R.7017.2035, subps. 1-2

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Table A of the permit.See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy: due 105 days after each PerformanceTest

The Notification, Test Plan, and Test Report may be submitted in an alternativeformat as allowed by Minn. R. 7017.2018.

18.0

CD Minn. R. 7017.2025, subp. 3 Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof a subsequent performance test on the same unit as specified by Minn. R.7017.2025, subp. 3. The limit is final upon issuance of a permit amendmentincorporating the change.

19.0

CD hdr MONITORING REQUIREMENTS20.0

CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration: The Permittee shall calibrate all requiredmonitoring equipment at least once every 12 months (any requirements applying tocontinuous emission monitors are listed separately in this permit).

21.0

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/orC, monitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.

22.0

CD hdr RECORDKEEPING23.0

CD Title I Condition: to avoidclassification as a major sourceunder 40 CFR Section 52.21 andMinn. R. 7007.3000; To avoidclassification as a major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200; To avoidmajor source classification under40 CFR Section 63.2

Monthly VOC Emissions Calculations: by the 15th day of each month, thePermittee shall calculate and record the following:

1. total facility VOC emissions during the previous month using the followingequation:

TFE = (LR1 + LR2 + TS + TW + TL + FE + TP + EG)/2000

where:

TFE = total terminal facility monthly VOC emissions, tonsLR1 = loading rack 1 emissions calculated under EU 001, lb/monthLR2 = loading rack 2 emissions calculated under EU 002, lb/monthTS = storage tank standing losses calculated under GP 001, lb/monthTW = storage tank working losses calculated under GP 001, lb/monthTL = tank roof landing emissions calculated under GP 001, lb/monthFE = fugitive emissions calculated under FS 001, lb/monthTP = tanker purging emissions calculated under FS 002, lb/monthEG = emergency generator emissions calculated under EU 004, lb/month

2. total facility 12-month rolling sum VOC emissions by summing the monthly VOCemissions from the previous 12 months.

24.0

CD Minn. R. 7007.0800, subp. 5(C);meets requirement of 40 CFRSection 60.7(f) & Minn. R.7019.0100, subp. 1

Recordkeeping: Retain all records at the stationary source, unless otherwisespecified within this permit, for a period of five (5) years from the date of monitoring,sample, measurement, or report. Records which must be retained at this locationinclude all calibration and maintenance records, all original recordings forcontinuous monitoring instrumentation, and copies of all reports required by thepermit. Records must conform to the requirements listed in Minn. R. 7007.

25.0

CD Minn. R. 7007.0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.

26.0




22 May, 2013 16:18Page 3 of 28

CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. These records shall be kept for a period of fiveyears from the date that the change was made. The records shall be kept at thestationary source for the current calendar year of operation and may be kept at thestationary source or office of the stationary source for all other years. The recordsmay be maintained in either electronic or paper format.

27.0

CD hdr REPORTING/SUBMITTALS28.0

CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown.However, notification is not required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.

29.0

CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of any regulated air pollutant.The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is notrequired in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when the breakdownis over.

30.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.

31.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment Report:Within 2 working days of discovery, notify the Commissioner in writing of anydeviation from permit conditions which could endanger human health or theenvironment. Include the following information in this written description:1. the cause of the deviation;2. the exact dates of the period of the deviation, if the deviation has been corrected;3. whether or not the deviation has been corrected;4. the anticipated time by which the deviation is expected to be corrected, if not yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.

32.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearfollowing Permit Issuance. The first semiannual report submitted by the Permitteeshall cover the calendar half-year in which the permit is issued. The first report ofeach calendar year covers January 1 - June 30. The second report of eachcalendar year covers July 1 - December 31. If no deviations have occurred, thePermittee shall submit the report stating no deviations.

33.0

CD Minn. R. 7007.1150 - 7007.1500 Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.

34.0

CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).

35.0




22 May, 2013 16:18Page 4 of 28

S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year followingPermit Issuance (for the previous calendar year). The Permittee shall submit this tothe Commissioner on a form approved by the Commissioner. This report covers alldeviations experienced during the calendar year.

36.0

CD Minn. R. 7019.3000 - 7019.3100 Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance, to be submitted on a form approved by the Commissioner.

37.0

CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 60 days after receipt of an MPCA bill.38.0




22 May, 2013 16:18Page 5 of 28

Subject Item: GP 001 Storage Tanks

Associated Items: TK 001 Tank 103 Ethanol

TK 002 Tank 104 Ethanol

TK 003 Tank 105 Ethanol

TK 004 Tank 106 Gasoline







TK 012 Diesel Fuel

TK 013 Gasoline additive

NC/CA


CD Title I Condition: To avoidclassification as major sourceunder 40 CFR Section 52.21 andMinn. R. 7007.3000; To avoidclassification as a major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200; To avoidmajor source classification under40 CFR Section 63.2; Minn. R.7007.0800, subps. 4 and 5

Recordkeeping - Gasoline Throughput:

By the 15th day of each month the Permittee shall calculate and record gasolinethroughput during the previous calendar month as follows:

1. TK 004 (Tank 106) throughput;

2. TK 005, TK 006, TK 007, TK 008, TK 009, and TK 010 (Tank 107 - Tank 112)total throughput.

1.0


Recordkeeping - Tank Landings: by the 15th day of each month the Permittee shallcalculate and record the following:

1. the combined total tank landings for TK 005, TK 006, TK 007, TK 008, TK 009,and TK 010 during the previous calendar month;

2. the total tank landings for TK 004 during the previous calendar month.

2.0


Standing Losses Calculations:

By the 15th day of each month, calculate and record total tanks standing lossesusing the following equation for the previous calendar month:

TS = 3*A + B + 6*C + D + E = 4051 lb/month

where:

TS = total standing losses (lbs/month)A = ethanol tank standing loss factor, 128 lb/month/tankB = Tank 106 (TK 004) rim seal, deck fitting, and deck seam emission factor, 360lb/monthC = Tanks 107 - 112 (TK 005 - TK 010) rim seal, deck fitting, and deck seam lossemission factor, 551 lb/month/tankD = Detergent Additive Tank (TK 013) standing emission factor, 1.09 lb/monthE = Fuel Oil Tank B (TK 012) standing emission factor, 0.20 lb/month

Revise the above equation as needed for tanks taken out of service.

3.0




22 May, 2013 16:18Page 6 of 28


Working Losses Calculations:

By the 15th day of each month, calculate and record total tanks working losses forthe previous calendar month using the following equation:

TW = F*G + H*I + J*K + L*M + N*O

where:

TW = working losses (lbs/month)F = ethanol tanks (TO 001 - TK 003) working loss factor, 4.70*10^-4 lbs/galG = monthly total combined ethanol throughput, gal/monthH = Tank 106 (TK 004) working loss factor, 3.02*10^-6 lbs/galI = Tank 106 monthly gasoline throughput, gal/monthJ = Tanks 107 - 112 (TK 005 - TK 010) working loss factor, 2.02*10^-6 lbs/galK = Tanks 107 - 112 monthly gasoline throughput, gal/monthL = Detergent Additive Tank (TK 013) working loss factor, 1.06*10^-4 lbs/galM = Detergent Additive Tank monthly throughput, gal/monthN = Fuel Oil Tank B (TK 012) working loss factor, 1.44*10^-5 lbs/galO = Fuel Oil Tank B monthly throughput

Monthly throughputs are in gallons.

4.0


Tank Landing Emission Calculations:

By the 15th day of each month, calculate and record total tank landing emissionsfor the previous month using the following equation:

TL = P*Q + R*S

TL = Tank Landing Emissions (lb/month)P = emission factor, 2660 lb/landing for TK 005 - TK 010Q = total number of tank roof landings during the previous month for TK 005 - TK010R = emission factor, 1196 lb/landing for TK 004S = total number of TK 004 roof landings for the previous month

5.0




22 May, 2013 16:18Page 7 of 28

Subject Item: GP 002 40 CFR pt. 63, subp. BBBBBB Requirements, Enforcement Not Delegated to MPCA.

Associated Items: CE 001 Flaring

CE 002 Vapor Recovery System-Condensers, Hoods, & Other Enclosures

EU 001 Loading Rack 1 - gasoline

MR 001 Temperature reading

MR 002 VRU CEMS, NDIR Gas Analyzer








NC/CA


CD hdr 40 CFR pt. 63, subp. BBBBBB Requirements, Enforcement Not Delegated toMPCA.

1.0

CD 40 CFR Sections 63.11089(e) and63.11083(b)

This facility meets the definition of an existing bulk gasoline terminal, a gasolinestorage and distribution facility that receives gasoline by pipeline, ship or barge, orcargo tank and has a gasoline throughput of 20,000 gallons per day or greater.Gasoline throughput shall be the maximum calculated design throughput as definedat 40 CFR Section 63.11100.

2.0

CD 40 CFR Section 63.11081 (i) For any affected source subject to the provisions of this subpart and anotherFederal rule, The Permittee may elect to comply only with the more stringentprovisions of the applicable subparts. They must consider all provisions of therules, including monitoring, recordkeeping, and reporting. The Permittee mustidentify the affected source and provisions with which they will comply in theNotification of Compliance Status required under 40 CFR Section 63.11093. Theyalso must demonstrate in your Notification of Compliance Status that eachprovision with which the Permittee will comply is at least as stringent as theotherwise applicable requirements in this subpart.

3.0

CD 40 CFR Section 63.11081 (i) The Permittee is responsible for making accurate determinations concerning themore stringent provisions; noncompliance with this rule is not excused if it is laterdetermined that your determination was in error, and, as a result, The Permittee isviolating this subpart. Compliance with this rule is the responsibility of ThePermittee's, and the Notification of Compliance Status does not alter or affect thatresponsibility.

4.0

CD 40 CFR Section 63.11085 (a) The Permittee must, at all times, operate and maintain any affected source,including associated air pollution control equipment and monitoring equipment, in amanner consistent with safety and good air pollution control practices forminimizing emissions. Determination of whether such operation and maintenanceprocedures are being used will be based on information available to theAdministrator, which may include, but is not limited to, monitoring results, review ofoperation and maintenance procedures, review of operation and maintenancerecords, and inspection of the source .

5.0

CD 40 CFR Section 63.11087(a); 40CFR Section 60.112(b); Minn. R.7011.1520

For each gasoline storage tank with a capacity of greater than or equal to 75 cubicmeters, the Permittee must equip each internal floating roof gasoline storage tankaccording to the requirements in 40 CFR Section 60.112b(a)(1), except for thesecondary seal requirements under 40 CFR Section 60.112b(a)(1)(ii)(B) and therequirements in 40 CFR Section 60.112b(a)(1)(iv) through (ix)

6.0




22 May, 2013 16:18Page 8 of 28


For each gasoline terminal loading rack with a gasoline throughput of greater thanor equal to 250,000 gallons per day, where gallons per day is calculated bysumming the current day's throughput, plus the throughput for the previous 364days, and then dividing that sum by 365, the Permittee must:(a) Equip loading rack(s) with a vapor collection system designed to collect theTOC vapors displaced from cargo tanks during product loading; and(b) Reduce emissions of TOC to less than or equal to 80 mg/l of gasoline loadedinto gasoline cargo tanks at the loading rack; and

7.0


continued:

(c) Design and operate the vapor collection system to prevent any TOC vaporscollected at one loading rack or lane from passing through another loading rack orlane to the atmosphere; and(d) Limit the loading of gasoline into gasoline cargo tanks that are vapor tight usingthe procedures specified in 40 CFR Section 60.502(e) through (j) of this chapter.For the purposes of this section, the term �tank truck� as used in 40 CFR Section60.502(e) through (j) of this chapter means �cargo tank� as defined in 40 CFRSection 63.11100 .

8.0

CD 40 CFR Section 63.11087 (b);Minn. R. 7011.1520

The Permittee shall comply with the requirements of this subpart by the applicabledates specified in 40 CFR Section 63.11083, except that storage vessels equippedwith floating roofs and not meeting the requirements of paragraph (a) of this sectionmust be in compliance at the first degassing and cleaning activity after January 10,2011 or by January 10, 2018, whichever is first .

9.0

CD hdr INSPECTION REQUIREMENTS10.0

CD 40 CFR Sections 63.11089(a) and63.11100

Monthly Leak Inspections: The Permittee shall perform a monthly leak inspection ofall equipment in gasoline service, as defined in 40 CFR Section 63.11100. For thisinspection, detection methods incorporating sight, sound, and smell are acceptable.

40 CFR Section 63.11100 defines 'in gasoline service' as a piece of equipmentused in a system that transfers gasoline or gasoline vapors and 'monthly' as onceper calendar month at regular intervals of no less than 28 days and no more than35 days.

11.0

CD 40 CFR Section 63.11089(b) Leak Inspection Recordkeeping: A log book shall be used and shall be signed bythe Permittee at the completion of each inspection. A section of the log book shallcontain a list, summary description, or diagram(s) showing the location of allequipment in gasoline service at the facility.

12.0

CD 40 CFR Section 63.11089(c) Each detection of a liquid or vapor leak shall be recorded in the log book. When aleak is detected, an initial attempt at repair shall be made as soon as practicablebut no later than 5 calendar days after the leak is detected. Repair or replacementof leaking equipment shall be completed within 15 calendar days after detection ofeach leak, except as provided in the requirement listed below (referring to 40 CFRSection 63.11089(d)).

13.0

CD 40 CFR Section 63.11089(d) Delay of Equipment Leak Repair: Delay of repair of leaking equipment will beallowed if the repair is not feasible within 15 days. The Permittee shall provide inthe semiannual Excess Emissions Report specified in 40 CFR Section63.11095(b), the reason(s) why the repair was not feasible and the date each repairwas completed.

14.0

CD 40 CFR Section 63.11092(b) The Permittee shall install, calibrate, certify, operate, and maintain, according to themanufacturer's specifications, a continuous monitoring system (CMS) whilegasoline vapors are displaced to the vapor processor systems. As specified below:

(1) This includes MR 001, Flare CMS for CE 001 and

(2) MR 002, VRU CEMS, for CE 002.

15.0

CD 40 CFR Section63.11092(b)(1)(i)(A)

The Permittee shall monitor the operation of CE 002 using MR 003, a continuousemissions monitoring system (CEMS), or, when using CE001, monitor CE001 usingMR001 continuous monitoring system (CMS).

16.0

CD hdr TESTING AND MONITORING REQUIREMENTS17.0




22 May, 2013 16:18Page 9 of 28

CD 40 CFR Section 63.11092(a) The Permittee shall conduct a performance test on the vapor processing andcollection systems (CE 002) according to either 40 CFR Section 63.11092(a)(1)(i)or (a)(1)(ii).

Test method specifications for 40 CFR Section 63.11092(a)(1)(i) is described in theperformance test requirements for EU 001 with the exception that a reading of 500parts per million shall be used to determine the level of leaks to be repaired.

18.0

CD 40 CFR Section 63.11092(a)(4) The performance test requirements of 40 CFR Section 63.11092(a) do not apply toflares defined in 40 CFR Section 63.11100 and meeting the flare requirements in40 CFR Section 63.11(b). The Permittee shall demonstrate that the flare andassociated vapor collection system is in compliance with the requirements in 40CFR Sections 63.11(b) and 60.503(a), (b), and (d).

19.0

CD 40 CFR Section 63.11094(b) The Permittee shall keep records of the test results for each gasoline cargo tankloading at the facility as specified below:

(1) Annual certification testing performed under 40 CFR Section 63.11092(f)(1).

20.0

CD 40 CFR Section 63.11094(b),continued

continued:

(2) The documentation file shall be kept up-to-date for each gasoline cargo tankloading at the facility. The documentation for each test shall include, as a minimum,the following information:(i) Name of test: Annual Certification Test Method 27 or Periodic Railcar BubbleLeak Test Procedure.(ii) Cargo tank owner's name and address.(iii) Cargo tank identification number.(iv) Test location and date.(v) Tester name and signature.(vi) Witnessing inspector, if any: Name, signature, and affiliation.(vii) Vapor tightness repair: Nature of repair work and when performed in relation tovapor tightness testing.(viii) Test results: Test pressure; pressure or vacuum change, mm of water; timeperiod of test; number of leaks found with instrument; and leak definition .

21.0


continued:

(3) If the Permittee is complying with the alternative requirements in 40 CFRSection 63.11088(b), they must keep records documenting that the Permittee hasverified the vapor tightness testing according to the requirements of theAdministrator .

22.0

CD 40 CFR Section 63.11092(c) For performance tests performed after the initial test required by 40 CFR Section63.11092(a), the Permittee shall document the reasons for any change in theoperating parameter value since the previous performance test.

23.0

CD 40 CFR Section 63.11092(d) The Permittee shall:

(1) Operate the vapor processing system in a manner not to exceed or not to gobelow, as appropriate, the operating parameter value for the parameters describedin 40 CFR Section 63.11092(b)(1).

(2) In cases where an alternative parameter pursuant to 40 CFR Section63.11092(b)(1)(iv) or (b)(5)(i) is approved, the Permittee shall operate the vaporprocessing system in a manner not to exceed or not to go below, as appropriate,the alternative operating parameter value.

(3) Operation of the vapor processing system in a manner exceeding or goingbelow the operating parameter value, as appropriate, shall constitute a violation ofthe emission standard in 40 CFR Section 63.11088(a), except as specified in 40CFR Section 63.11092(d)(4).

24.0

CD 40 CFR Sections 63.11092(e)(1)and 60.113b(a); Minn. R.7011.1520

For each gasoline storage tanks equipped with an internal floating roof, thePermittee must perform inspections of the floating roof system according to therequirements of 40 CFR Section 60.113b(a).

25.0

CD 40 CFR Section 63.11092(f) The annual certification test for each gasoline cargo tank shall consist of the testmethods specified in 40 CFR Section 63.11092(f)(1) or (2). Facilities that are alsosubject to 40 CFR pt. 60, subp. XX may elect, after notification to the MPCA, tocomply with 40 CFR Section 63.11092(f)(1) or (2)..

26.0




22 May, 2013 16:18Page 10 of 28

CD 40 CFR Section 63.11092 (g) Conduct of performance tests. Performance tests conducted for this subpart shallbe conducted under such conditions as the Administrator specifies to the owner oroperator, based on representative performance ( i.e., performance based onnormal operating conditions) of the affected source. Upon request, the owner oroperator shall make available to the Administrator such records as may benecessary to determine the conditions of performance tests.

27.0

CD 40 CFR Section63.11092(b)(1)(iii)(B)(2)

The Permittee shall develop and submit to the Administrator a monitoring andinspection plan that describes the Permittee's approach for meeting the followingrequirements:

1) CE 001 and CE 002 shall be equipped to automatically prevent gasoline loadingoperations from beginning at any time that the pilot flame is absent at CE 001, orthe VOC CEMS indicates CE 002 is not operating within its operating parameterlimit. The shutdown requirement will apply to the control device (CE 001 or CE 002)which is in active service.

2) The Permittee shall verify, during each day of operation of EU 001, the properoperation of the assist-air blower, the vapor line valve, and the emergencyshutdown system. Verification shall be through visual observation or through anautomated alarm or shutdown system that monitors and records system operation.A manual or electronic record of the start and end of a shutdown event may beused.

28.0

CD 40 CFR Section63.11092(b)(1)(iii)(B)(2), continued

continued:

3) The Permittee shall perform semi-annual preventive maintenance inspections ofthe thermal oxidation system and carbon adsoption systems, including theautomated alarm or shutdown system for those units so equipped, according to therecommendations of the manufacturer of the system.

4) The monitoring plan shall specify conditions that would be considered CE 001and 002 malfunctions during the inspections or automated monitoring performedunder 40 CFR Section 63.11092(b)(1)(iii)(B)(2)(ii) and (iii), describe specificcorrective actions that will be taken to correct any malfunction, and define what thePermittee would consider to be a timely repair for each potential malfunction.

29.0

CD 40 CFR Section63.11092(b)(1)(iii)(B)(2), continued

continued:

5) The Permittee shall document any CE 001 and CE 002 malfunction, as definedin the monitoring and inspection plan, and any activation of the automated alarm orshutdown system with a written entry into a log book or other permanent form ofrecord. Such record shall also include a description of the corrective action takenand whether such corrective actions were taken in a timely manner, as defined inthe monitoring and inspection plan, as well as an estimate of the amount ofgasoline loaded during the period of the malfunction.

30.0

CD 40 CFR Section 63.11092(b)(3)and (4)

The Permittee shall determine an operating parameter value based on theparameter data monitored during the performance test, supplemented byengineering assessments and the manufacturer's recommendations.

The Permittee shall provide for the Administrator's approval the rationale for theselected operating parameter value, monitoring frequency, and averaging time,including data and calculations used to develop the value and a description of whythe value, monitoring frequency, and averaging time demonstrate continuouscompliance with the emission standard in 40 CFR Section 63.11088(a).

31.0

CD 40 CFR Section63.11092(d)(1)-(3)

The Permittee shall:(1) Operate the vapor processing system in a manner not to exceed or not to gobelow, as appropriate, the operating parameter value for the parameters describedin 40 CFR Section 63.11092(b)(1).(2) Operation of the vapor processing system in a manner exceeding or goingbelow the operating parameter value, as appropriate, shall constitute a violation ofthe emission standard in 40 CFR Section 63.11088(a), except as specified in 40CFR Section 63.11092(d)(4).

32.0

CD 40 CFR Section 63.11094(a) The Permittee shall keep records as specified in 40 CFR Section 60.115b, exceptrecords shall be kept for at least 5 years.

33.0

CD hdr RECORDKEEPING34.0

CD 40 CFR Section 63.11094(d) The Permittee shall prepare and maintain a record describing the types,identification numbers, and locations of all equipment in gasoline service. If thePermittee elects to implement an instrument program under 40 CFR Section63.11089, the record shall contain a full description of the program.

35.0




22 May, 2013 16:18Page 11 of 28

CD 40 CFR Section 63.11094(e) The Permittee shall record in the log book for each leak that is detected theinformation specified below:(1) The equipment type and identification number.(2) The nature of the leak (i.e. vapor or liquid) and the method of detection (i.e.sight, sound, or smell).(3) The date the leak was detected and the date of each attempt to repair the leak.(4) Repair methods applied in each attempt to repair the leak.(5) A statement of: Repair Delayed and the reason for the delay if the leak is notrepaired within 15 calendar days after discovery of the leak.(6) The expected date of successful repair of the leak if the leak is not repairedwithin 15 days.(7) The date of successful repair of the leak.

36.0

CD 40 CFR Section 63.11094(f) The Permittee shall:(1) Keep an up-to-date, readily accessible record of the continuous monitoring datarequired under 40 CFR Section 63.11092(b) or 63.11092(e). This record shallindicate the time intervals during which loadings of gasoline cargo tanks haveoccurred or, alternatively, shall record the operating parameter data only duringsuch loadings. The date and time of day shall also be indicated at reasonableintervals on this record.

37.0

CD 40 CFR Section 63.11094(f),continued

(2) Record and report simultaneously with the Notification of Compliance Statusrequired under 40 CFR Section 63.11093(b) all data and calculations, engineeringassessments, and manufacturer's recommendations used in determining theoperating parameter value under 40 CFR Section 63.11092(b) or 63.11092(e).(ii) The following information when using a flare under provisions of 63.11(b) tocomply with:(A) Flare design (i.e., steam-assisted, air-assisted, or non-assisted); and(B) All visible emissions (VE) readings, heat content determinations, flow ratemeasurements, and exit velocity determinations made during the compliancedetermination required under 40 CFR Section 63.11092(e)(3).

38.0

CD 40 CFR Section 63.11094(f),continued

(3) Keep an up-to-date, readily accessible copy of the monitoring and inspectionplan required under 40 CFR Section 63.11092(b)(1)(i)(B)(2) or (iii)(B)(2).

(4) Keep an up-to-date, readily accessible record of all system malfunctions, asspecified in 40 CFR Section 63.11092(b)(1)(i)(B)(2)(v) or (iii)(B)(2)(v).

(5) If a Permittee requests approval to use a vapor processing system or monitoran operating parameter other than those specified in 40 CFR Section 63.11092(b),the Permittee shall submit a description of planned reporting and recordkeepingprocedures.

39.0

CD 40 CFR Section 63.11094(g) The Permittee shall keep the following records:

1) Records of the occurrence and duration of each malfunction of operation ( i.e.,process equipment) or the air pollution control and monitoring equipment.2) Records of actions taken during periods of malfunction to minimize emissions inaccordance with 40 CFR Section 63.11085(a), including corrective actions torestore malfunctioning process and air pollution control and monitoring equipmentto its normal or usual manner of operation.

40.0

CD 40 CFR Section 63.11093 (c) and(d)

The Permittee shall under this subpart must submit a Notification of PerformanceTest, as specified in 40 CFR Section 63.9(e), prior to initiating testing required by40 CFR Sections 63.11092(a) or 63.11092(b) and other additional notificationsspecified in 40 CFR Section 63.9, as applicable.

41.0

CD 40 CFR Section 63.11094 (3)(c) As an alternative to keeping records at the terminal of each gasoline cargo tanktest result as required in paragraph (b) of this section, The Permitte may complywith the requirements in either paragraph (c)(1) or paragraph (c)(2) of this section.This includes:(1) An electronic copy of each record is instantly available at the terminal.(i) The copy of each record in paragraph (c)(1) of this section is an exact duplicateimage of the original paper record with certifying signatures.(ii) The Administrator is notified in writing that each terminal using this alternative isin compliance with paragraph (c)(1) of this section.

42.0




22 May, 2013 16:18Page 12 of 28

CD 40 CFR Section 63.11094 (3)(c)(2) For facilities that use a terminal automation system to prevent gasoline cargo tanksthat do not have valid cargo tank vapor tightness documentation from loading (e.g.,via a card lock-out system), a copy of the documentation is made available (e.g.,via facsimile) for inspection by the Administrator's delegated representatives duringthe course of a site visit, or within a mutually agreeable time frame.(i) The copy of each record in paragraph (c)(2) of this section is an exact duplicateimage of the original paper record with certifying signatures.(ii) The Administrator is notified in writing that each terminal using this alternative isin compliance with paragraph (c)(2) of this section.

43.0

CD hdr REPORTING44.0

CD 40 CFR Section 63.11095(a) The Permittee shall also include the following in the Semiannual Deviations Report(lsited in Table B of this permit), as applicable:1) For storage vessels complying with option 2(b) in Table 1 of 40 CFR pt. 63,subp. BBBBBB, the information specified in 40 CFR Section 60.115b(a),60.115b(b), or 60.115b(c), depending upon the control equipment installed;2) For loading racks, each loading of a gasoline cargo tank for which vaportightness documentation had not been previously obtained by the facility; and3) For equipment leak inspections, the number of equipment leaks not repairedwithin 15 days after detection.

45.0

CD 40 CFR Section 63.11095(b) The Permittee shall submit a semiannual excess emissions (EER) report to theAdministrator, as defined in 40 CFR Section 63 subpart BBBBBB, with theSemiannual Deviations Report listed in this permit. Excess emissions events, andthe information to be included in the excess emissions report, are as follows:(1) Each instance of a non-vapor-tight gasoline cargo tank loading at the facility inwhich the Permittee failed to take steps to assure that such cargo tank would notbe reloaded at the facility before vapor tightness documentation for that cargo tankwas obtained.(2) Each reloading of a non-vapor-tight gasoline cargo tank at the facility beforevapor tightness documentation for that cargo tank is obtained by the facility inaccordance with 40 CFR Section 63.11094(b).

46.0


continued:(3) Each exceedance or failure to maintain, as appropriate, the monitored operatingparameter value determined under 40 CFR Section 63.11092(b). The report shallinclude the monitoring data for the days on which exceedances or failures tomaintain have occurred, and a description and timing of the steps taken to repair orperform maintenance on the vapor collection and processing systems or the CMS.(4) Each instance in which malfunctions discovered during the monitoring andinspections required under 40 CFR Section 63.11092(b)(1)(i)(B)(2) and (iii)(B)(2)were not resolved according to the necessary corrective actions described in themonitoring and inspection plan. The report shall include a description of themalfunction and the timing of the steps taken to correct the malfunction.

47.0


continued:(5) For each occurrence of an equipment leak for which no repair attempt wasmade within 5 days or for which repair was not completed within 15 days afterdetection:(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.

48.0

CD 40 CFR Section 63.11095(d) The Permittee shall submit a semiannual report including the number, duration, anda brief description of each type of malfunction which occurred during the reportingperiod and which caused or may have caused any applicable emission limitation tobe exceeded. The report must also include a description of actions taken by thePermittee during a malfunction to minimize emissions in accordance with 40 CFRSection 63.11085(a), including actions taken to correct a malfunction. The reportmay be submitted as a part of the semiannual compliance report.

49.0




22 May, 2013 16:18Page 13 of 28

Subject Item: EU 001 Loading Rack 1 - gasoline

Associated Items: CE 001 Flaring

CE 002 Vapor Recovery System-Condensers, Hoods, & Other Enclosures

GP 002 40 CFR pt. 63, subp. BBBBBB Requirements, Enforcement Not Delegated to MPCA.



SV 001 Loading Rack 1 - gasoline

SV 003 VRU

NC/CA



Recordkeeping - Gasoline Loading:

By the 15th day of each month the Permittee shall calculate and record the gallonsof gasoline loaded during the previous calendar month. Gasoline includesgasoline/ethanol blends and E-85.

1.0


Loading Emissions Calculations:

By the 15 day of each month the Permittee shall calculate and record the VOCloading emissions from the previous month using the following equation:

LR1 = ([0.987 *gal_CE002 * a] + [0.987 *gal_CE001 * b] + [0.013 * (gal_CE001 +gal_CE002)*c] + [d * c])/1000

where:

LR1 = Loading Rack 1 monthly emissions, lbs/monthgal_CE002 = gallons of gasline loaded the previous month, CE 002 in servicegal_CE001 = gallons of gasoline loaded the previous month, CE 001 in servicea = VRU controlled emission factor in lb/mgal (currently 0.083 lb/mgal [based on 10mg/liter manufacturer guarantee], or as revised based on performance testing)b = flare controlled emission factor in lb/mgal (currently 0.14 lb/mgal [based on 35mg/liter], or as revised based on performance testing)c = uncontrolled emission factor (8.15 lb/mgal)d = gallons of gasoline loaded, CE 001 and CE 002 out of service

2.0


During operation of loading rack 1, emissions shall be vented to and controlled byeither the VRU (CE 002) or the flare (CE 001).

3.0

CD hdr STANDARDS FOR VOC EMISSIONS4.0

LIMIT 40 CFR Section 60.502(b);Minn. R. 7011.1550

Volatile Organic Compounds: less than or equal to 35 milligrams/liter of productloaded.

5.0

CD 40 CFR Section 60.502(a) & (d);Minn. R. 7011.1550

EU 001 shall be equipped with a vapor collection system designed to collect thetotal organic compounds vapors displaced from tank trucks during product loading.

The vapor collection system shall be designed to prevent any total organiccompounds vapors collected at EU 001 from passing to another loading rack.

6.0




22 May, 2013 16:18Page 14 of 28

CD 40 CFR Section 60.502(e);Minn. R. 7011.1550

(e) Loadings of liquid product into gasoline tank trucks shall be limited to vapor-tightgasoline tank trucks using the following procedures:

(1) The Permittee shall obtain the vapor tightness documentation described inSection 60.505(b) for each gasoline tank truck which is to be loaded at the affectedfacility.

(2) The Permittee shall require the tank identification number to be recorded aseach gasoline tank truck is loaded at the affected facility.

continued

7.0

CD 40 CFR Section 60.502(e)(continued);Minn. R. 7011.1550

(3)(i) The Permittee shall cross-check each tank identification number obtained inSection 60.502(e)(2) with the file of tank vapor tightness documentation within 2weeks after the corresponding tank is loaded, unless either of the followingconditions is maintained:

(A) If less than an average of one gasoline tank truck per month over the last 26weeks is loaded without vapor tightness documentation then the documentationcross-check shall be performed each quarter; or

(B) If less than an average of one gasoline tank truck per month over the last 52weeks is loaded without vapor tightness documentation then the documentationcross-check shall be performed semiannually.

(ii) If either the quarterly or semiannual cross-check reveals that these conditionswere not maintained, the source must return to biweekly monitoring until such timeas these conditions are again met.

continued

8.0

CD 40 CFR Section 60.502(e)(continued);Minn. R. 7011.1550

(4) The Permittee shall notify the owner or operator of each non-vapor-tightgasoline tank truck loaded at the affected facility within 1 week of thedocumentation cross-check in Section 60.502(e)(3).

(5) The Permittee shall take steps assuring that the nonvapor-tight gasoline tanktruck will not be reloaded at the affected facility until vapor tightness documentationfor that tank is obtained.

(6) Alternate procedures to those described in Section 60.502(e)(1) through (5) forlimiting gasoline tank truck loadings may be used upon application to, and approvalby, the Administrator.

9.0

CD 40 CFR Section 60.502(f) & (g);Minn. R. 7011.1550

(f) The Permittee shall act to assure that loadings of gasoline tank trucks at theaffected facility are made only into tanks equipped with vapor collection equipmentthat is compatible with the EU 001 vapor collection system.

(g) The Permittee shall act to assure that the EU 001 and the tank truck vaporcollection systems are connected during each loading of a gasoline tank truck atthe affected facility. Examples of actions to accomplish this include training driversin the hookup procedures and posting visible reminder signs at the affected loadingracks.

10.0

CD 40 CFR Section 60.502(h) - (j);Minn. R. 7011.1550

(h) The vapor collection and liquid loading equipment shall be designed andoperated to prevent gauge pressure in the delivery tank from exceeding 4,500pascals (450 mm of water) during product loading. This level is not to be exceededwhen measured by the procedures specified in Section 60.503(d).

(i) The EU 001 vapor collection system pressure-vacuum vent shall not open at asystem pressure less than 4,500 pascals (450 mm of water).

(j) Each calendar month, the vapor collection system, the vapor processing system,and EU 001 shall be inspected during the loading of gasoline tank trucks for totalorganic compounds liquid or vapor leaks. For purposes of this paragraph, detectionmethods incorporating sight, sound, or smell are acceptable. Each detection of aleak shall be recorded and the source of the leak repaired within 15 calendar daysafter it is detected.

11.0

CD hdr TEST METHODS AND PROCEDURES12.0

S/A 40 CFR Section 60.8(a);Minn. R. 7017.2020, subp. 1

Performance Test: due before 04/23/2014 after CE 002 is installed. Testing shall beconducted according to the requirements specified in 40 CFR Section 60.503.

This satisfies the test requirements found at 40 CFR Section 63.11092 (a)(1).

13.0




22 May, 2013 16:18Page 15 of 28

CD 40 CFR Section 60.503(a) & (b);Minn. R. 7011.1550

(a) In conducting the performance tests required in Section 60.8, the Permitteeshall use as reference methods and procedures the test methods in appendix A ofpart 60 part or other methods and procedures as specified in Section 60.8, exceptas provided in Section 60.8(b). The three-run requirement of Section 60.8(f) doesnot apply to this subpart.

(b) Immediately before the performance test required to determine compliance withSection 60.502(b) and (h), the Permittee shall use Method 21 to monitor forleakage of vapor all potential sources in the EU 001 vapor collection systemequipment while a gasoline tank truck is being loaded. The Permittee shall repairall leaks with readings of 10,000 ppm (as methane) or greater before conductingthe performance test.

14.0

CD 40 CFR Section 60.503(c);Minn. R. 7011.1550

(c) The Permittee shall determine compliance with the standards in Section60.502(b) as follows:

(1) The performance test shall be 6 hours long during which at least 300,000 litersof gasoline is loaded. If this is not possible, the test may be continued the same dayuntil 300,000 liters of gasoline is loaded or the test may be resumed the next daywith another complete 6-hour period. In the latter case, the 300,000-liter criterionneed not be met. However, as much as possible, testing should be conductedduring the 6-hour period in which the highest throughput normally occurs.

continued

15.0

CD 40 CFR Section 60.503(c)(continued);Minn. R. 7011.1550

(2) If the EU 001 vapor processing system is intermittent in operation, theperformance test shall begin at a reference vapor holder level and shall end at thesame reference point. The test shall include at least two startups and shutdowns ofthe vapor processor. If this does not occur under automatically controlledoperations, the system shall be manually controlled.

(3) The emission rate (E) of total organic compounds shall be computed using theequation in Appendix I of this permit.

continued

16.0


(4) The performance test shall be conducted in intervals of 5 minutes. For eachinterval "i", readings from each measurement shall be recorded, and the volumeexhausted (Vesi) and the corresponding average total organic compoundsconcentration (Cei) shall be determined. The sampling system response time shallbe considered in determining the average total organic compounds concentrationcorresponding to the volume exhausted.

(5)(i) Method 2B shall be used to determine the volume (Vesi) air-vapor mixtureexhausted at each interval.

17.0


(6) Method 25A or 25B shall be used for determining the total organic compoundsconcentration (Cei) at each interval. The calibration gas shall be either propane orbutane. The Permittee may exclude the methane and ethane content in the exhaustvent by any method (e.g., Method 18) approved by the Administrator.

(7) To determine the volume (L) of gasoline dispensed during the EU 001performance test, facility records or readings from EU 001 gasoline dispensingmeters shall be used.

18.0

CD 40 CFR Section 60.503(d);Minn. R. 7011.1550

(d) The Permittee shall determine compliance with the standard in Section60.502(h) as follows:

(1) A pressure measurement device (liquid manometer, magnehelic gauge, orequivalent instrument), capable of measuring up to 500 mm of water gaugepressure with ±2.5 mm of water precision, shall be calibrated and installed on theEU 001 vapor collection system at a pressure tap located as close as possible tothe connection with the gasoline tank truck.

(2) During the performance test, the pressure shall be recorded every 5 minuteswhile a gasoline truck is being loaded; the highest instantaneous pressure thatoccurs during each loading shall also be recorded. Every loading position must betested at least once during the performance test.

19.0

CD 40 CFR Section 60.503(f);Minn. R. 7011.1550

(f) The Permittee shall use alternative test methods and procedures in accordancewith the alternative test method provisions in Section 60.8(b) for flares that do notmeet the requirements in Section 60.18(b).

20.0




22 May, 2013 16:18Page 16 of 28

S/A Minn. R. 7017.2020, subp. 1 Testing Frequency Plan: due 60 days after Performance Test for VOC emissions.The plan shall specify a testing frequency based on the test results and MPCAguidance. Future performance tests at 12-month, 36-month, or 60-month intervals,or as applicable, shall be required upon written approval of the plan by the MPCA.

21.0

CD hdr RECORDKEEPING AND REPORTING22.0

CD Minn. R. 7007.0800, subps. 2 &5(C)

Records Retention Period: Minn. R. 7007.0800, subp. 5(C) requires recordretention for a period of five years. Although 40 CFR part 60 subp. XX requiresrecord retention for only a 2 or 3 year period, the Permittee shall meet the 5-yearretention requirement of Minn. R. 7007.0800, subp. 5(C) for all records required by40 CFR part 60 subp. XX.

23.0

CD 40 CFR Section 60.505(a) & (b);Minn. R. 7011.1550

(a) The tank truck vapor tightness documentation required under Section60.502(e)(1) shall be kept on file at the terminal in a permanent form available forinspection.

(b) The documentation file for each gasoline tank truck shall be updated at leastonce per year to reflect current test results as determined by Method 27. Thisdocumentation shall include, as a minimum, the following information:

(1) Test title: Gasoline Delivery Tank Pressure Test-EPA Reference Method 27.

(2) Tank owner and address.

(3) Tank identification number.

(4) Testing location.

(5) Date of test.

(6) Tester name and signature.

(7) Witnessing inspector, if any: Name, signature, and affiliation.

(8) Test results: Actual pressure change in 5 minutes, mm of water (average for 2runs).

24.0

CD 40 CFR Section 60.505(c) & (d);Minn. R. 7011.1550

(c) A record of each monthly leak inspection required under Section 60.502(j) shallbe kept on file at the terminal for at least 2 years. Inspection records shall include,as a minimum, the following information:

(1) Date of inspection.

(2) Findings (may indicate no leaks discovered; or location, nature, and severity ofeach leak).

(3) Leak determination method.

(4) Corrective action (date each leak repaired; reasons for any repair interval inexcess of 15 days).

(5) Inspector name and signature.

(d) The Permittee shall keep documentation of all notifications required underSection 60.502(e)(4) on file at the facility for at least 2 years.

25.0

CD 40 CFR Section 60.505(e)(1);Minn. R. 7011.1550

(e) As an alternative to keeping records at the facility of each gasoline cargo tanktest result as required in 40 CFR Section 60.505(a), (c), and (d), the Permittee maycomply with the requirements in either 40 CFR Section 60.505(e)(1) or 40 CFRSection 60.505(e)(2).

(1) An electronic copy of each record is instantly available at the facility.

(i) The copy of each record in Section 60.505(e)(1) is an exact duplicate image ofthe original paper record with certifying signatures.

(ii) The permitting authority is notified in writing that the facility is in compliance withSection 60.505(e)(1).

continued

26.0




22 May, 2013 16:18Page 17 of 28

CD 40 CFR Section 60.505(e)(2);Minn. R. 7011.1550

(2) For facilities that utilize a terminal automation system to prevent gasoline cargotanks that do not have valid cargo tank vapor tightness documentation from loading(e.g., via a card lock-out system), a copy of the documentation is made available(e.g., via facsimile) for inspection by permitting authority representatives during thecourse of a site visit, or within a mutually agreeable time frame.

(i) The copy of each record in Section 60.505(e)(2) is an exact duplicate image ofthe original paper record with certifying signatures.

(ii) The permitting authority is notified in writing that the facility is in compliance withSection 60.505(e)(2).

27.0

CD 40 CFR Section 60.505(f);Minn. R. 7011.1550

(f) The Permittee shall keep records of all replacements or additions of componentsperformed on an existing vapor processing system for at least 3 years.

28.0




22 May, 2013 16:18Page 18 of 28

Subject Item: EU 002 Loading Rack 2 - diesel fuel and loading

NC/CA



Recordkeeping - Fuel Oil Loading:

By the 15th day of each month for the previous month the Permittee shall calculateand record the gallons of No. 1 Fuel Oil and No. 2 Fuel Oil. Separate records ofeach fuel oil grade shall be kept.

1.0


Loading Rack 2 Emissions Calculations:

By the 15th day of each month the Permittee shall calculate and record the loadingrack 2 VOC emissions for the previous month using the following equation:

LR2 = [A1 * 0.0176 lb/mgal] + [D2 * 0.0134 lb/mgal])/1000

where:

LR2 = loading rack 2 monthly emissions, lb/monthA1 = gallons of No. 1 Fuel Oil loaded during the previous monthD2 = gallons of No. 2 Fuel Oil loaded during the previous month

2.0




22 May, 2013 16:18Page 19 of 28

Subject Item: EU 004 Diesel emergency generator

Associated Items: SV 005 Emergency Diesel Generator

NC/CA


CD Title I Condition: To avoidclassification as major source andmodification under 40 CFRSection 52.21 & Minn. R.7007.3000; to avoid major sourceclassification under 40 CFRSection 70.2 and Minn. R.7007.0200; To avoid major sourceclassification under 40 CFRSection 63.2; Minn. R. 7007.0800,subps. 4 and 5

Recordkeeping - Emergency Generator:

By the 15th day of each month for the previous month the Permittee shall recordthe hours of operation for EU 004.

1.0

CD Title I Condition: To avoidclassification as major source andmodification under 40 CFRSection 52.21 & Minn. R.7007.3000; to avoid major sourceclassification under 40 CFRSection 70.2 and Minn. R.7007.0200; To avoid major sourceclassification under 40 CFRSection 63.2; Minn. R. 7007.0800,subps. 4 and 5

Emergency Generator Emissions Calculations:

By the 15th day of each month the Permittee shall calculate and record theemergency generator VOC emissions for the previous month using the followingequation:

EG = 0.09 lb/MMBtu * 4.33 MMBtu/hr * MH

where:

MH = hours of operation for EU 004 recorded during the previous month

2.0

CD hdr EMISSION LIMITS3.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.

4.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input5.0

LIMIT Minn. R. 7007.0800, subp. 2 Sulfur Content of Fuel: less than or equal to 0.0015 percent by weight6.0

CD hdr OPERATIING CONDITIONS7.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: diesel fuel oil and diesel fuel oil blends only, by design.8.0

LIMIT Title I Condition: To avoidclassification as major source andmodification under 40 CFRSection 52.21 & Minn. R.7007.3000

Operating Hours: less than or equal to 500 hours/year using 12-month Rolling Sumto be calculated by the 15th day of each month.

9.0

CD hdr RECORDKEEPING REQUIREMENTS10.0

CD Minn. R. 7007.0800, subp. 4 & 5 Hours of Operation: The Permittee shall maintain documentation on site that theunit is an emergency generator by design that qualifies under the U.S. EPAmemorandum entitled "Calculating Potential to Emit (PTE) for EmergencyGenerators" dated September 6, 1995, limiting operation to 500 hours per year.

11.0

CD Minn. R. 7007.0800, subps. 4 & 5 Fuel Supplier Certification: The Permittee shall obtain and maintain a fuel suppliercertification for each shipment of diesel fuel and diesel fuel oil blend used in EU004, certifying that the sulfur content does not exceed 0.0015% by weight.

12.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage based on fuel supplyrecords. The Permittee shall keep a copy of all fuel delivery reports and purchaseorders for five years from the date of record or receipt.

13.0

CD hdr PART 63 SUBPART ZZZZ NESHAP REQUIREMENTS14.0

CD hdr PART 63 SUBPART ZZZZ NESHAP APPLICABILITY15.0

CD 40 CFR Section 63.6590(a)(2)(iii);Minn.R. 7011.8150

40 CFR pt. 63, subp. ZZZZ applies to each affected source. EU 004 is a newstationary RICE located at an area source that commenced construction on or afterJune 12, 2006 and is an affected soucre at the facility.

16.0

CD hdr PART 63 SUBPART ZZZZ NESHAP OPERATIONAL REQUIREMENTS17.0




22 May, 2013 16:18Page 20 of 28

CD 40 CFR Section 63.6590(c)(1);Minn.R. 7011.8150

EU 004 meets the criteria in 40 CFR Section 63.6590(c)(1) and shall meet therequirements of 40 CFR pt. 63, subp. ZZZZ by meeting the requirements of 40 CFRpt. 60, subp. IIII, for compression ignition engines. No further requirements applyfor EU 004 under 40 CFR pt. 63, subp. ZZZZ.

18.0

CD hdr PART 60 SUBPART IIII NSPS REQUIREMENTS19.0

CD hdr PART 60 SUBPART IIII NSPS APPLICABILITY20.0

CD 40 CFR Section 63.6590(a)(2)(iii);40 CFR Section 60.4200(a)(2)

For the purposes of 40 CFR pt. 60, subp. IIII, the date that constructioncommences is the date the engine is ordered by the Permittee. The Permittee is aowner and operator of EU 004 which is stationary CI ICE that commencedconstruction after July 11, 2005, and is manufactured after April 1, 2006.

21.0

CD 40 CFR Section 60.4200(a)(4) The provisions of 40 CFR Section 60.4208 are applicable to all owners andoperators of stationary CI ICE that commence construction after July 11, 2005.

22.0

CD hdr PART 60 SUBPART IIII NSPS LIMITS23.0

LIMIT 40 CFR Section 60.4205(b); 40CFR Section 60.4202(a)(2); 40CFR Section 89.112(a)

NMHC+NOx: less than or equal to 4.0 grams/kilowatt-hour exhaust emissions fromEU 004.

Exhaust emissions of nitrogen oxides, hydrocarbon, and nonmethane hydrocarbonare measured using the procedures in 40 CFR pt. 89, subp. E.

24.0


Carbon Monoxide: less than or equal to 3.5 grams/kilowatt-hour exhaust emissionsfrom EU 004.

Exhaust emissions of carbon monoxide are measured using the procedures in 40CFR pt. 89, subp. E.

25.0


Total Particulate Matter: less than or equal to 0.20 grams/kilowatt-hour exhaustemissions from EU 004.

Exhaust emissions of total particulate matter are measured using the CaliforniaRegulations for New 1996 and Later Heavy-Duty Off-Road Diesel Cycle Engines.

26.0

CD 40 CFR Section 60.4206 The Permittee shall operate and maintain EU 004 to achieve the emissionstandards as required in 40 CFR Section 60.4205 over the entire life of the engine.

27.0

CD hdr PART 60 SUBPART IIII NSPS OPERATIONAL REQUIREMENTS28.0

CD 40 CFR Section 60.4207(b) The Permittee shall use diesel fuel that meets the requirements of 40 CFR Section80.510(b) for nonroad diesel fuel.

29.0

CD 40 CFR Section 60.4208 (a) After December 31, 2008, the Permittee may not install stationary CI ICE(excluding fire pump engines) that do not meet the applicable requirements for2007 model year engines.

(b) After December 31, 2009, the Permittee may not install stationary CI ICE with amaximum engine power of less than 19 KW (25 HP) (excluding fire pump engines)that do not meet the applicable requirements for 2008 model year engines.

(c) After December 31, 2014, the Permittee may not install non-emergencystationary CI ICE with a maximum engine power of greater than or equal to 19 KW(25 HP) and less than 56 KW (75 HP) that do not meet the applicable requirementsfor 2013 model year non-emergency engines.

30.0

CD 40 CFR Section 60.4208 (cont.) (d) After December 31, 2013, the Permittee may not install non-emergencystationary CI ICE with a maximum engine power of greater than or equal to 56 KW(75 HP) and less than 130 KW (175 HP) that do not meet the applicablerequirements for 2012 model year non-emergency engines.

(e) After December 31, 2012, the Permittee may not install non-emergencystationary CI ICE with a maximum engine power of greater than or equal to 130 KW(175 HP), including those above 560 KW (750 HP), that do not meet the applicablerequirements for 2011 model year non-emergency engines.

(f) After December 31, 2016, the Permittee may not install non-emergencystationary CI ICE with a maximum engine power of greater than or equal to 560 KW(750 HP) that do not meet the applicable requirements for 2015 model yearnon-emergency engines.

31.0




22 May, 2013 16:18Page 21 of 28

CD 40 CFR Section 60.4208 (cont.) (g) After December 31, 2018, the Permittee may not install non-emergencystationary CI ICE with a maximum engine power greater than or equal to 600 KW(804 HP) and less than 2,000 KW (2,680 HP) and a displacement of greater than orequal to 10 liters per cylinder and less than 30 liters per cylinder that do not meetthe applicable requirements for 2017 model year non-emergency engines.

(h) In addition to the requirements specified in 40 CFR Sections 60.4201, 60.4202,60.4204, and 60.4205, the Permittee is prohibited to import stationary CI ICE with adisplacement of less than 30 liters per cylinder that do not meet the applicablerequirements specified in 40 CFR Section 60.4208(a) through (g) after the datesspecified in 40 CFR Section 60.4208(a) through (g).

(i) 40 CFR Section 60.4208 requirements do not apply to stationary CI ICE thathave been modified, reconstructed, and do not apply to engines that were removedfrom one existing location and reinstalled at a new location.

32.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(a)

(a) The Permittee shall do all of the following:

(1) Operate and maintain EU 004 and control device according to themanufacturer's emission-related written instructions;

(2) Change only those emission-related settings that are permitted by themanufacturer; and

(3) Meet the requirements of 40 CFR parts 89, 94 and/or 1068, as they apply to you

33.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(c)

The Permittee shall comply with the emission standards specified in 40 CFRSection 60.4205(b) by purchasing an engine certified to the emission standards in40 CFR Section 60.4205(b) as applicable, for the same model year and maximumengine power. The engine must be installed and configured according to themanufacturer's emission-related specifications.

34.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)

The Permittee shall operate EU 004 according to the requirements in 40 CFRSection 60.4211(f)(1) through (3). In order for the engine to be considered anemergency stationary ICE under 40 CFR pt. 60, subp. IIII, any operation other thanemergency operation, maintenance and testing, emergency demand response, andoperation in non-emergency situations for 50 hours per year, as described in 40CFR Section 60.4211(f)(1) through (3), is prohibited. If EU 004 is not operatedaccording to 40 CFR Section 60.4211(f)(1) through (3) requirements, the enginewill not be considered an emergency engine under 40 CFR pt. 60, subp. IIII andmust meet all requirements for non-emergency engines.

35.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(1)

(1) There is no time limit on the use of emergency stationary ICE in emergencysituations.

36.0

LIMIT 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(2)

Operating Hours: less than or equal to 100 hours/year for any combination of thepurposes specified in 40 CFR Section 60.4211(f)(2)(i) through (iii). Any operationfor non-emergency situations as allowed by 40 CFR Section 60.4211(f)(3) countsas part of the 100 hours/year limit.

37.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(2)(i)

(i) EU 004 may be operated for maintenance checks and readiness testing,provided that the tests are recommended by federal, state or local government, themanufacturer, the vendor, the regional transmission organization or equivalentbalancing authority and transmission operator, or the insurance companyassociated with the engine. The Permittee may petition the Administrator forapproval of additional hours to be used for maintenance checks and readinesstesting, but a petition is not required if the owner or operator maintains recordsindicating that federal, state, or local standards require maintenance and testing ofemergency ICE beyond 100 hours/year.

38.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(2)(ii) and (iii)

(ii) EU 004 may be operated for emergency demand response for periods in whichthe Reliability Coordinator under the North American Electric Reliability Corporation(NERC) Reliability Standard EOP-002-3, Capacity and Energy Emergencies(incorporated by reference, see 40 CFR Section 60.17), or other authorized entityas determined by the Reliability Coordinator, has declared an Energy EmergencyAlert Level 2 as defined in the NERC Reliability Standard EOP-002-3.

(iii) EU 004 may be operated for periods where there is a deviation of voltage orfrequency of 5 percent or greater below standard voltage or frequency.

39.0




22 May, 2013 16:18Page 22 of 28

LIMIT 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(3)

Operating Hours: less than or equal to 50 hours/year non-emergency hours of EU004. The 50 hours of operation in non-emergency situations are counted as part ofthe 100 hours/year for maintenance and testing and emergency demand responseprovided in 40 CFR Section 60.4211(f)(2). Except as provided in 40 CFR Section60.4211(f)(3)(i), the 50 hours per calendar year for non-emergency situationscannot be used for peak shaving or non-emergency demand response, or togenerate income for a facility to an electric grid or otherwise supply power as partof a financial arrangement with another entity.

40.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(3)(i)(A) through(D)

The 50 hours per year for non-emergency situations can be used to supply poweras part of a financial arrangement with another entity if all of the followingconditions are met:

(A) The engine is dispatched by the local balancing authority or local transmissionand distribution system operator;

(B) The dispatch is intended to mitigate local transmission and/or distributionlimitations so as to avert potential voltage collapse or line overloads that could leadto the interruption of power supply in a local area or region.

(C) The dispatch follows reliability, emergency operation or similar protocols thatfollow specific NERC, regional, state, public utility commission or local standards orguidelines.

(D) The power is provided only to the Permittee or to support the local transmissionand distribution system.

41.0

CD 40 CFR Section 60.4209; 40 CFRSection 60.4211(f)(3)(i)(E)

(E) The Permittee identifies and records the entity that dispatches the engine andthe specific NERC, regional, state, public utility commission or local standards orguidelines that are being followed for dispatching the engine. The local balancingauthority or local transmission and distribution system operator may keep theserecords on behalf of the engine owner or operator.

42.0

CD Minn. R. 7007.0800, subp. 2 The Permittee shall install a non-resettable hour meter prior to startup of theengine.

43.0

CD 40 CFR Section 60.4214(b) The Permittee is not required to submit an initial notification. If the emergencyengine does not meet the standards applicable to non-emergency engines in theapplicable model year in 40 CFR pt. 60, subp. IIII, Table 5 the Permittee shall keeprecords of the operation of the engine in emergency and non-emergency servicethat are recorded through the non-resettable hour meter. The owner must recordthe time of operation of the engine and the reason the engine was in operationduring that time.

44.0

CD 40 CFR Section 60.4214(d)(1) If EU 004 operates or is contractually obligated to be available for more than 15hours per calendar year for the purposes specified in 40 CFR Section60.4211(f)(2)(ii) and (iii), or operates for the purposes specified in 40 CFR Section60.4211(f)(3)(i), and the Permittee shall submit an annual report according to therequirements below:

(1) The report must contain the following information:

(i) Company name and address where the engine is located.

(ii) Date of the report and beginning and ending dates of the reporting period.

(iii) Engine site rating and model year.

(iv) Latitude and longitude of the engine in decimal degrees reported to the fifthdecimal place.

(v) Hours operated for the purposes specified in 40 CFR Section 60.4211(f)(2)(ii)and (iii), including the date, start time, and end time for engine operation for thepurposes specified in 40 CFR 60.4211(f)(2)(ii) and (iii).

45.0




22 May, 2013 16:18Page 23 of 28

CD 40 CFR Section 60.4214(d)(1)(cont.)

(vi) Number of hours the engine is contractually obligated to be available for thepurposes specified in 40 CFR Section 60.4211(f)(2)(ii) and (iii).

(vii) Hours spent for operation for the purposes specified in 40 CFR Section60.4211(f)(3)(i), including the date, start time, and end time for engineoperation for the purposes specified in 40 CFR Section60.4211(f)(3)(i). Thereport must also identify the entity that dispatched the engine and the situationthat necessitated the dispatch of the engine

46.0

S/A 40 CFR Section 60.4214(d)(2) Annual Report: due before end of each calendar year starting 03/31/2016. The firstannual report must cover the calendar year 2015 and must be submitted no laterthan March 31, 2016. Subsequent annual reports for each calendar year must besubmitted no later than March 31 of the following calendar year.

47.0

CD 40 CFR Section 60.4214(d)(3) The annual report must be submitted electronically using the subpart specificreporting form in the Compliance and Emissions Data Reporting Interface (CEDRI)that is accessed through EPA's Central Data Exchange (CDX) ( www.epa.gov/cdx). However, if the reporting form specific to 40 CFR pt. 60, subp. IIII is not availablein CEDRI at the time that the report is due, the written report must be submitted tothe Administrator at the appropriate address listed in 40 CFR Section 60.4.

48.0

CD 40 CFR Section 60.4218 40 CFR pt. 60, subp. IIII, Table 8 shows which parts of the General Provisions in 40CFR Sections 60.1 through 60.19 that apply to the Permittee.

49.0




22 May, 2013 16:18Page 24 of 28

Subject Item: CE 001 Flaring

Associated Items: EU 001 Loading Rack 1 - gasoline



NC/CA



When loading rack emission are vented to the flare, the presence of a flare pilotflame shall be monitored using an ultraviolet sensor or any other equivalent deviceto detect the presence of a flame. Sensor readings shall be either electronicallyrecorded, manually recorded at 15 minute intervals, or printed on a continuous hardcopy readout.

1.0




22 May, 2013 16:18Page 25 of 28

Subject Item: CE 002 Vapor Recovery System-Condensers, Hoods, & Other Enclosures

Associated Items: EU 001 Loading Rack 1 - gasoline



NC/CA



CEMS Installation: Install VRU CEMS (MR 002: VRU CEMS, NDIR Gas Analyzer).1.0

CD Minn. R. 7007.0800, subps. 4 & 5 When loading rack emissions are vented to the VRU, VOCs shall be monitoredusing continuous emissions monitoring system (CEMS). Emissions shall be eitherelectronically recorded, manually recorded at 15 minute intervals, or printed on acontinuous hard copy readout.

2.0

CD Minn. R. 7007.0800, subps. 4 & 5 Install, calibrate, certify, operate, and maintain, according to the manufacturer'sspecificaitons, a continuous emissions monitoring system (CEMS) capable ofmeasuring organic compound concentration in the exhaust air stream.

3.0

CD 40 CFR Section 63.8(c)(4)(ii);Minn. R. 7017.1040, subp. 1

CEMS Monitor Design: Each CEMS shall be designed to complete a minimum ofone cycle of sampling, analyzing, and data recording in each 15-minute period.

4.0

S/A Minn. R. 7017.1040, subp. 1 Notification: due 60 days before Install of the continuous emissions monitoringsystem. The notification shall include plans and drawings of the system.

5.0

S/A Minn. R. 7017.1040, subp. 1 CEM Certification Test: due 120 days after Initial Startup. (This requirement is asstringent as that of Minn. R. 7017.1050, subp. 1 requiring testing within 90 daysafter the due date of the first excess emissions report required for the CEMS orCOMS.)

6.0

CD 40 CFR Section 63.8(e)(2);Minn. R. 7017.1060, subps. 1 & 2

CEMS Certification Test Plan: due 60 days before CEMS Certification Test.7.0

CD Minn. R. 7017.1060, subp. 3 CEMS Certification Test Pretest Meeting: due 7 days before CEMS CertificationTest.

8.0

CD 40 CFR Section 63.8(e)(5);Minn. R. 7017.1080, subps. 1, 2,& 4

CEMS Certification Test Report: due 45 days after CEMS Certification Test9.0

CD Minn. R. 7017.1080, subp. 3 CEMS Certification Test Report - Microfiche or CD Copy: due 105 days afterCEMS Certification Test.

10.0

CD 40 CFR Section 63.8(b)(4);Minn. R. 7017.1090, subp. 1

Continuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

11.0

S/A Minn. R. 7017.1110, subps. 1 & 2 Excess Emissions/Downtime Reports (EER's): due 30 days after end of eachcalendar quarter following Initial Startup of the Monitor The EER shall indicate allperiods of monitor bypass and all periods of exceedances of the limit includingexceedances allowed by an applicable standard, i.e. during startup, shutdown, andmalfunctions.

12.0

CD Minn. R. 7017.1170, subp. 2; 40CFR pt. 60, App. F; section 3

QA Plan: Develop and implement a written quality assurance plan that covers eachCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by 40CFR pt. 60, Appendix F, Section 3.

13.0




22 May, 2013 16:18Page 26 of 28

S/A 40 CFR pt. 60, Appendix F,section 5.1.2; Minn. R. 7017.1170,subp. 4

Cylinder Gas Audit: due 30 days after end of each calendar half-year followingCEM Certification Test, except that a CGA is not required during any calendar halfyear in which a RATA was performed. The initial CGA must be performed within180 days following certification of the CEMS. The CGAs shall be conducted at leastthree months apart but no more than eight months apart. A CGA shall beconducted according to the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.If the monitored emission unit was operated for less than 24 hours during thecalendar half year, a CGA is not required for that calendar half year.

14.0

CD Minn. R. 7017.1170, subp. 5 CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar yearfollowing Permit Issuance. A RATA is not required in any calendar year if a RATAconducted in the previous year demonstrated a relative accuracy value of less than15 percent or if the associated emissions unit operated less than 48 hours duringthe calendar year. If the exception is used, the next RATA shall be conductedduring the first half of the following calendar year. RATAs shall be conducted atleast 3 months apart according to 40 CFR pt. 60, Appendix F, section 5.1.1.

15.0

CD Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar quarter following Cylinder Gas Audit (CGA).

16.0

CD Minn. R. 7017.1180, subp. 2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMSRelative Accuracy Test Audit (RATA)) .

17.0

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end ofeach calendar quarter following permit issuance in which a RATA was conducted.

18.0

CD 40 CFR Section 63.10(b)(1);Minn. R. 7017.1130

Recordkeeping: The owner or operator must retain records of all CEMS monitoringdata and support information for a period of five years from the date of themonitoring sample, measurement or report. Records shall be kept at the source.

19.0

CD 40 CFR Section 63.8(g)(2)regarding continuous monitoringsystems other than COMS;Minn. R. 7017.1160

Monitoring Data: Reduce all VRU CEMS, NDIR Gas Analyzer data to 1-houraverages, in accordance with 40 CFR Section 63.8(g)(2) and Minn. R. 7011.1160.1-hour averages shall be computed from four or more data points equally spacedover each 1-hour period.

20.0




22 May, 2013 16:18Page 27 of 28

Subject Item: FS 001 Valves, Flanges, & Seals

NC/CA


CD Title I Condition: to avoidclassification as major sourceunder 40 CFR Section 52.21 and40 CFR Section 63.2; Minn. R.7007.3000;

Minn. R. 7007.0800, subp. 2 toavoid major source classificationunder section 70.2; Minn. R.7007.0800, subp. 4 & 5

The Permittee shall keep an updated record of the FS 001 inventory. The inventoryshall state the number of valves, flanges, and pump seals. As of May 2008 therewere 152 valves, 686 flanges, and 17 pump seals.

1.0



Fugitive Emissions Calculations:

By the 15th day of each month, calculate and record fugitive VOC emissions fromthe previous month as follows:

FE = T*U + V*W + X*Y

where:

FE = fugitive emissions, lb/monthT = total valve countU = valve emission factor, 6.92*10^-2 lb/month/valveV = total flange countW = flange emission factor, 1.29*10^-2 lb/month/flangeX = total pump seal countY = pump seal emission factor, 8.68*10^-1 lb/month/seal

2.0




22 May, 2013 16:18Page 28 of 28

Subject Item: FS 002 Tanker Purging

NC/CA




Recordkeeping - Tanker Purging:

By the 15th day of each month the Permittee shall calculate and record thefollowing:

1. total number of 8500 gallon cargo tankers purged during the previous calendarmonth;

2. monthly purging emissions from the previous calendar month as follows:

TP = Z*AA*8500

where:

TP = tanker purging emissions, lb/monthZ = purging emission factor, 0.00815 lb/gallon gasolineAA = total number of 8500 gallon tanker purged during the previous month

1.0


Attachment 3: Points Calculator

Points Calculator

1) AQ Facility ID No.: 16300010 Total Points 552) Facility Name: Newport Terminal Corp3) Small business? y/n? n 4) DQ Numbers (including all rolled) : 4146, 2301, 2725, 2784 5) Date of each Application Received: 10/02/12, 05/08/08, 08/28/2003, NA; respectively6) Final Permit No. 1630010-0057) Permit Staff Andrea Walkush8) "Work completed" in which .xls file (i.e. unit 2b, unit 1a, biofuels)? NA

TotalApplication Type DQ No. Qty. Points Points DetailsAdministrative Amendment 1 0Minor Amendment 4 0Applicability Request 10 0Moderate Amendment 15 0Major Amendment 4146 1 25 25Individual State Permit (not reissuance) 50 0Individual Part 70 Permit (not reissuance) 75 0

Additional PointsModeling Review 15 0

BACT Review 15 0LAER Review 15 0CAIR/Part 75 CEM analysis 10 0NSPS Review 4146 1 10 10NESHAP Review 4146 1 10 10Case-by-case MACT Review 20 0Netting 10 0Limits to remain below threshold 4146 1 10 10Plantwide Applicability Limit (PAL) 20 0AERA review 15 0Variance request under 7000.7000 35 0Confidentiality request under 7000.1300 2 0EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0Part 4410.4300, subparts 8, items A & B; 10, items A to C; 16, items A & D; 17, items A to C & E to G; and 18, items B & C

35 0

Part 4410.4300, subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D

70 0

Add'l Points 30

NOTES:

(DQ DQ 4146)


Attachment 4: Caterpillar Diesel Generator Information

DIESEL GENERATOR SET

STANDBY400 ekW 500 kVA60 Hz 1800 rpm 480 VoltsCaterpillar is leading the power generationmarketplace with Power Solutions engineeredto deliver unmatched flexibility, expandability,reliability, and cost-effectiveness.

Image shown may notreflect actual package.

FEATURES

FUEL/EMISSIONS STRATEGY• EPA Certified for Stationary

Emergency Application(EPA Tier 3 emissions levels)

DESIGN CRITERIA• The generator set accepts 100% rated load in one

step per NFPA 110 and meets ISO 8528-5 transientresponse.

UL 2200• UL 2200 listed packages available. Certain

restrictions may apply. Consult with your Cat®Dealer.

FULL RANGE OF ATTACHMENTS• Wide range of bolt-on system expansion

attachments, factory designed and tested• Flexible packaging options for easy and cost

effective installation

SINGLE-SOURCE SUPPLIER• Fully prototype tested with certified torsional

vibration analysis available

WORLDWIDE PRODUCT SUPPORT• Cat dealers provide extensive post sale support

including maintenance and repair agreements• Cat dealers have over 1,800 dealer branch stores

operating in 200 countries• The Cat® S•O•SSM program cost effectively detects

internal engine component condition, even thepresence of unwanted fluids and combustionby-products

CAT® C15 ATAAC DIESEL ENGINE• Utilizes ACERT™ Technology• Reliable, rugged, durable design• Field-proven in thousands of applications

worldwide• Four-stroke diesel engine combines consistent

performance and excellent fuel economy withminimum weight

• Electronic engine control

CAT GENERATOR• Matched to the performance and output

characteristics of Cat engines• Load adjustment module provides engine relief

upon load impact and improves load acceptanceand recovery time

• UL 1446 Recognized Class H insulation

CAT EMCP 4 CONTROL PANELS• Simple user friendly interface and navigation• Scalable system to meet a wide range of

customer needs• Integrated Control System and Communications

Gateway

STANDBY 400 ekW 500 kVA60 Hz 1800 rpm 480 Volts

FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT

System Standard OptionalAir Inlet • Light Duty Air filter

• Service indicator[ ] Single element air filter[ ] Dual element air filter[ ] Heavy-duty dual element air filter with precleaner[ ] Air inlet shut-off

Cooling • Radiator package mounted• Coolant level sight gauge• Coolant drain line with valve• Fan and belt guards• Cat® Extended Life Coolant

[ ] Radiator duct flange[ ] Low coolant level sensor

Exhaust • Dry exhaust manifold• Stainless steel flex fittings with split-cuff connection• Exhaust flange outlet

[ ] Industrial [ ] Residential [ ] Critical Mufflers[ ] Manifold and turbocharger guards[ ] Elbows and through-wall kits

Fuel • Primary fuel filter with integral water separator• Secondary fuel filters• Fuel priming pump• Engine fuel transfer pump• Fuel cooler*• Flexible fuel lines*Not included with packages without radiators

[ ] Integral dual wall UL listed fuel tank base[ ] Sub-base dual wall UL listed fuel tank base[ ] Manual transfer pump[ ] Fuel level switch

Generator • Class H insulation• Self excited (SE)• Class H temperature rise• VR6 voltage regulator with 3-phase sensing with load

adjustment module• IP23 protection

[ ] Oversize generators[ ] Permanent magnet excitation (PMG)[ ] Internal excited (IE)[ ] Cat digital voltage regulator (CDVR) with kVAR/PF[ ] Anti-condensation space heaters[ ] Coastal Insulation Protection (CIP)[ ] Reactive droop

Power Termination • Power Center houses EMCP controller andpower/control terminations (rear mounted)

• Power terminal strips (NEMA or IEC mechanical lugholes)

• Segregated low voltage wiring termination panel• IP22 protection• Bottom cable entry

[ ] Power Center mounting option (right side)[ ] Circuit breakers,UL listed, 3 pole (80% & 100%

Rated)[ ] Circuit breakers,IEC compliant,3-4 pole(100% Rated)[ ] Multiple circuit breaker options[ ] C.B. Shunt trips[ ] C.B. Auxiliary contacts

Governor • ADEM™A4 [ ] Load share module

Control Panel • EMCP 4.1 (Rear-mounted in Power Center)• Speed adjustment• Voltage adjustment• Emergency stop pushbutton

[ ] EMCP 4.2[ ] Local annuniciator module (NFPA 99/110)[ ] Remote annunicator module (NFPA 99/110)[ ] Digital I/O module

Lube • Lubricating oil• Oil drain line with valves• Oil filter and dipstick• Fumes disposal• Lube oil level indicator• Oil cooler

[ ] Oil temperature sensor[ ] Manual sump pump

Mounting • Formed steel narrow base frame• Linear vibration isolation-seismic zone 4

[ ] Oil skid base[ ] Formed steel wide base frame

Starting/Charging • 24 volt starting motor• 24 volt, 45 amp charging alternator

[ ] Jacket water heater[ ] Block heater[ ] Ether starting aid[ ] Oversize batteries[ ] Battery disconnect switch[ ] Battery chargers (5 or 10 amp)[ ] Batteries with rack and cables

General • Paint - Caterpillar Yellow except rails and radiatorsgloss black

• Flywheel housing - SAE No.1

[ ] UL 2200 package[ ] CSA Certification[ ] Weather protective enclosure[ ] Sound attenuated protective enclosure

June 13 2011 13:49 PM2


SPECIFICATIONS

CAT GENERATOR

Frame size................................................................ LC6114BExcitation........................................................ Self ExcitationPitch.............................................................................. 0.6667Number of poles...................................................................4Number of bearings...................................... Single bearingNumber of Leads.............................................................. 012Insulation....................... UL 1446 Recognized Class H withtropicalization and antiabrasion- Consult your Caterpillar dealer for available voltagesIP Rating.........................................................Drip Proof IP23Alignment.............................................................. Pilot ShaftOverspeed capability........................................................125Wave form Deviation (Line to Line)................................. 2%Voltage regulator................................Three phase sensingVoltage regulation............Less than +/- 1/2% (steady state)Less than +/- ½% (w/ 3% speed change)Telephone influence factor...............................Less than 50Harmonic Distortion.........................................Less than 5%

CAT DIESEL ENGINE

C15 ATAAC, I-6, 4-Stroke Water-cooled DieselBore.......................................................... 137.20 mm (5.4 in)Stroke..................................................... 171.40 mm (6.75 in)Displacement...........................................15.20 L (927.56 in3)Compression Ratio....................................................... 16.1:1Aspiration........................................... Air-to-Air AftercooledFuel System................................................................... MEUIGovernor Type................ Caterpillar ADEM control system

CAT EMCP 4 SERIES CONTROLS

EMCP 4 controls including:- Run / Auto / Stop Control- Speed and Voltage Adjust- Engine Cycle Crank- 24-volt DC operation- Environmental sealed front face- Text alarm/event descriptions

Digital indication for:- RPM- DC volts- Operating hours- Oil pressure (psi, kPa or bar)- Coolant temperature- Volts (L-L & L-N), frequency (Hz)- Amps (per phase & average)- ekW, kVA, kVAR, kW-hr, %kW, PF (4.2 only)

Warning/shutdown with common LED indication of:- Low oil pressure- High coolant temperature- Overspeed- Emergency stop- Failure to start (overcrank)- Low coolant temperature- Low coolant level

Programmable protective relaying functions:- Generator phase sequence- Over/Under voltage (27/59)- Over/Under Frequency (81 o/u)- Reverse Power (kW) (32) (4.2 only)- Reverse reactive power (kVAr) (32RV)- Overcurrent (50/51)

Communications:- Four digital inputs (4.1)- Six digital inputs (4.2 only)- Four relay outputs (Form A)- Two relay outputs (Form C)- Two digital outputs- Customer data link (Modbus RTU) (4.2 only)- Accessory module data link (4.2 only)- Serial annunciator module data link (4.2 only)- Emergency stop pushbutton

Compatible with the following:- Digital I/O module- Local Annunciator- Remote CAN annunciator- Remote serial annunciator

June 13 2011 13:50 PM3


TECHNICAL DATA

Open Generator Set - - 1800 rpm/60 Hz/480 Volts DM8151EPA Certified for Stationary Emergency Application(EPA Tier 3 emissions levels)

Generator Set Package PerformanceGenset Power rating @ 0.8 pfGenset Power rating with fan

500 kVA400 ekW

Fuel Consumption100% load with fan75% load with fan50% load with fan

120.6 L/hr 31.9 Gal/hr97.5 L/hr 25.8 Gal/hr72.0 L/hr 19.0 Gal/hr

Cooling System1

Air flow restriction (system)Air flow (max @ rated speed for radiator arrangement)Engine Coolant capacity with radiator/exp. tankEngine coolant capacityRadiator coolant capacity

0.12 kPa 0.48 in. water720 m³/min 25427 cfm57.8 L 15.3 gal20.8 L 5.5 gal37.0 L 9.8 gal

Inlet AirCombustion air inlet flow rate 38.8 m³/min 1370.2 cfm

Exhaust SystemExhaust stack gas temperatureExhaust gas flow rateExhaust flange size (internal diameter)Exhaust system backpressure (maximum allowable)

487.7 ° C 909.9 ° F103.5 m³/min 3655.1 cfm152.4 mm 6.0 in6.8 kPa 27.3 in. water

Heat RejectionHeat rejection to coolant (total)Heat rejection to exhaust (total)Heat rejection to atmosphere from engineHeat rejection to atmosphere from generator

165 kW 9384 Btu/min463 kW 26331 Btu/min81 kW 4606 Btu/min29.2 kW 1660.6 Btu/min

Alternator2

Motor starting capability @ 30% voltage dipFrameTemperature Rise

880 skVALC6114B150 ° C 270 ° F

Lube SystemSump refill with filter 60.0 L 15.9 gal

Emissions (Nominal)3

NOx g/hp-hrCO g/hp-hrHC g/hp-hrPM g/hp-hr

3.49 g/hp-hr.35 g/hp-hr.04 g/hp-hr.034 g/hp-hr

1 For ambient and altitude capabilities consult your Cat dealer. Air flow restriction (system) is added to existing restriction from factory.2 Generator temperature rise is based on a 40° C (104° F) ambient per NEMA MG1-32. Some packages may have oversized generatorswith a different temperature rise and motor starting characteristics.3 Emissions data measurement procedures are consistent with those described in EPA CFR 40 Part 89, Subpart D & E and ISO8178-1 formeasuring HC, CO, PM, NOx. Data shown is based on steady state operating conditions of 77°F, 28.42 in HG and number 2 diesel fuelwith 35° API and LHV of 18,390 btu/lb. The nominal emissions data shown is subject to instrumentation, measurement, facility andengine to engine variations. Emissions data is based on 100% load and thus cannot be used to compare to EPA regulations which usevalues based on a weighted cycle.

June 13 2011 13:50 PM4


RATING DEFINITIONS AND CONDITIONS

Meets or Exceeds International Specifications: AS1359,CSA, IEC60034-1, ISO3046, ISO8528, NEMA MG 1-22,NEMA MG 1-33, UL508A, 72/23/EEC, 98/37/EC,2004/108/ECStandby - Output available with varying load for theduration of the interruption of the normal source power.Average power output is 70% of the standby powerrating. Typical operation is 200 hours per year, withmaximum expected usage of 500 hours per year.Standby power in accordance with ISO8528. Fuel stoppower in accordance with ISO3046. Standby ambientsshown indicate ambient temperature at 100% load whichresults in a coolant top tank temperature just below theshutdown temperature.

Ratings are based on SAE J1349 standard conditions.These ratings also apply at ISO3046 standard conditions.Fuel rates are based on fuel oil of 35º API [16º C (60º F)]gravity having an LHV of 42 780 kJ/kg (18,390 Btu/lb)when used at 29º C (85º F) and weighing 838.9 g/liter(7.001 lbs/U.S. gal.). Additional ratings may be availablefor specific customer requirements, contact your Catrepresentative for details. For information regarding LowSulfur fuel and Biodiesel capability, please consult yourCat dealer.

June 13 2011 13:50 PM5


DIMENSIONS

Package DimensionsLength 3775.1 mm 148.63 inWidth 1110.0 mm 43.7 inHeight 2091.0 mm 82.32 inWeight 3339 kg 7,361 lb

NOTE: For reference only - do not use forinstallation design. Please contactyour local dealer for exact weightand dimensions. (GeneralDimension Drawing #2781050).

www.Cat-ElectricPower.com

© 2011 CaterpillarAll rights reserved.

Materials and specifications are subject to change without notice.The International System of Units (SI) is used in this publication.

CAT, CATERPILLAR, their respective logos, "Caterpillar Yellow," the"Power Edge" trade dress, as well as corporate and product identity used

herein, are trademarks of Caterpillar and may not be used withoutpermission.

17794296

Performance No.: DM8151

Feature Code: C15DE7A

Gen. Arr. Number: 2351203

Source: U.S. Sourced

June 13 2011

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GEN SET PACKAGE PERFORMANCE DATA [DM8151]

AUGUST 06, 2012

For Help Desk Phone Numbers Click here

Performance Number: DM8151 Change Level: 02

Sales Model: C15 DITA Combustion: DI Aspr: TA

Engine Power:

619 HP

400 W/F EKW

416 W/O F EKW Speed: 1,800 RPM After Cooler: ATAAC

Manifold Type: DRY Governor Type: ELEC After Cooler Temp(F): 120

Turbo Quantity: 1 Engine App: GP Turbo Arrangement: Hertz: 60 Application Type: PACKAGE-DIE Engine Rating: PGS Strategy:

Rating Type: STANDBY Certification: EPA TIER-3 2005 - ----EPA STAT EMERC 2011 - ----

General Performance Data 1

GEN W/F EKW

PERCENT LOAD

ENGINE POWER

BHP

ENGINE BMEP

PSI

FUEL BSFC

LB/BHP-HR

FUEL RATE GPH

INTAKE MFLD TEMP DEG F

INTAKE MFLD P IN-HG

INTAKE AIR

FLOW CFM

EXH MFLD TEMP DEG F

EXH STACK TEMP DEG F

EXH GAS

FLOW CFM

400 100 619 293.56 0.36 31.86 119.66 66.1 1,370.21 1,210.28 909.86 3,655.07

360 90 557 264.41 0.37 29.11 118.94 61.39 1,296.05 1,181.12 894.74 3,414.93

320 80 497 235.69 0.38 26.89 116.6 57.81 1,257.2 1,155.2 880.7 3,266.61

300 75 467 221.48 0.39 25.76 114.98 55.61 1,228.95 1,142.24 873.86 3,181.85

280 70 437 207.26 0.39 24.52 113 52.71 1,193.64 1,128.02 867.02 3,072.38

240 60 378 179.27 0.41 21.9 108.5 45.9 1,105.35 1,095.62 852.98 2,811.05

200 50 319 151.57 0.42 19.02 103.46 37.7 992.34 1,057.1 838.4 2,486.16

160 40 264 125.46 0.42 15.82 97.88 27.84 840.49 997.88 809.96 2,065.91

120 30 208 98.63 0.42 12.55 92.3 17.74 688.64 917.6 766.04 1,635.07

100 25 179 85.14 0.43 10.91 89.42 12.62 610.94 869.18 737.96 1,416.12

80 20 150 71.36 0.43 9.33 87.08 8.32 547.38 813.02 701.24 1,221.89

40 10 92 43.37 0.5 6.55 85.46 3.88 473.22 673.52 592.34 957.03

General Performance Data 2

GEN W/F EKW

PERCENT LOAD

ENGINE POWER

BHP

COMPRESS OUT

PRESS IN-HG

COMPRESS OUT

TEMP DEG F

400 100 619 69.47 387.32

360 90 557 63.99 366.8

320 80 497 60.56 354.74

300 75 467 58.4 347.36

280 70 437 55.44 337.46

240 60 378 48.45 312.26

200 50 319 40.01 279.68

160 40 264 29.91 233.96

Page 1 of 9Performance Data

08/06/2012http://tmiwebclassic.cat.com/tmi/servlet/TMIDirector?Action=buildtab&refkind=RNTMI...

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120 30 208 19.57 187.16

100 25 179 14.3 163.4

80 20 150 9.89 142.88

40 10 92 5.15 117.14



Engine Heat Rejection Data

GEN W/F EKW

PERCENT LOAD

REJ TO JW

BTU/MN

REJ TO ATMOS BTU/MN

REJ TO EXHAUST BTU/MN

EXH RCOV TO

350F BTU/MN

FROM OIL CLR BTU/MN

FROM AFT CLR BTU/MN

WORK ENERGY BTU/MN

LHV ENERGY BTU/MN

HHV ENERGY BTU/MN

400 100 9,383.5 4,595.1 26,330.8 17,857.1 3,651.1 6,483.2 26,217.0 68,585.1 73,077.8

360 90 8,814.8 4,248.2 24,340.3 16,378.5 3,338.3 5,687.0 23,657.9 62,613.7 66,708.4

320 80 8,359.9 3,980.9 22,975.4 15,298.0 3,082.4 5,288.9 21,041.9 57,893.5 61,646.9

300 75 8,132.4 3,855.8 22,179.2 14,729.3 2,951.6 5,061.4 19,790.7 55,448.1 59,030.9

280 70 7,904.9 3,770.5 21,269.3 14,103.7 2,809.4 4,720.2 18,539.6 52,775.2 56,187.4

240 60 7,336.2 3,605.6 19,222.0 12,625.1 2,508.0 3,980.9 16,037.3 47,088.3 50,216.1

200 50 6,767.5 3,372.4 16,833.5 10,919.0 2,183.8 3,071.0 13,535.0 40,946.3 43,619.2

160 40 6,085.1 3,190.4 13,762.5 8,758.0 1,814.2 2,047.3 11,203.4 34,065.1 36,283.0

120 30 5,402.6 2,832.1 10,577.8 6,483.2 1,438.8 1,137.4 8,814.8 27,013.2 28,776.2

100 25 5,004.5 2,536.4 9,042.3 5,345.8 1,251.1 796.2 7,620.6 23,487.3 24,965.9

80 20 4,549.6 2,314.6 7,620.6 4,322.1 1,069.2 511.8 6,369.4 20,075.1 21,383.1

40 10 3,582.8 1,956.3 5,345.8 2,559.1 750.7 284.4 3,867.1 14,103.7 15,070.5



EMISSIONS DATA

EPA TIER-3 2005 - ---- *************************************************** D7 Gaseous emissions data measurements are consistent with those described in 40 CFR, EU 97/68/EC, ECE Regulation No. 96 and ISO 8178 for measuring HC, CO, PM, and NOx. Gaseous emissions values are WEIGHTED CYCLE AVERAGES and are in compliance with the following non-road regulations: LOCALITY AGENCY/LEVEL MAX LIMITS - g/kW-hr ------------------ ------------ ----------------------------------- U. S. (incl Calif) EPA/TIER-3 CO:3.5 NOx + HC:4.0 PM:0.2 EPA STAT EMERC 2011 - ---- *************************************************** P4 EPA EMERGENCY STATIONARY GASEOUS EMISSIONS DATA MEASUREMENTS ARE CONSISTENT WITH THOSE DESCRIBED IN EPA 40 CFR PART 60 SUBPART IIII AND ISO 8178 FOR MEASURING HC, CO, PM, AND NOX. GASEOUS EMISSIONS VALUES ARE WEIGHTED CYCLE AVERAGES AND ARE IN COMPLIANCE WITH THE NON-ROAD REGULATIONS. LOCALITY AGENCY/LEVEL MAX LIMITS - g/kW-hr ----------------- ------------------ ----------------------------- U.S. (INCL CALIF) EPA/STAT EMERGENCY CO:3.5 NOx + HC:4.0 PM:0.20

REFERENCE EXHAUST STACK DIAMETER 6 IN

WET EXHAUST MASS 6,241.3 LB/HR

WET EXHAUST FLOW (908.60 F STACK TEMP ) 3,658.60 CFM

WET EXHAUST FLOW RATE ( 32 DEG F AND 29.98 IN HG ) 1,292.00 STD CFM

DRY EXHAUST FLOW RATE ( 32 DEG F AND 29.98 IN HG ) 1,183.40 STD CFM

FUEL FLOW RATE 32 GAL/HR



RATED SPEED "Not to exceed data"

GEN PWR EKW

PERCENT LOAD

ENGINE POWER

BHP

TOTAL NOX (AS

NO2) LB/HR

TOTAL CO

LB/HR

TOTAL HC

LB/HR

PART MATTER

LB/HR

OXYGEN IN

EXHAUST PERCENT

400 100 619 5.7600 .8800 .1100 .0900 10.1000

300 75 467 2.8500 2.9400 .1600 .0900 11.2000

200 50 319 1.7200 3.5800 .2000 .1200 12.0000

100 25 179 1.6900 1.4100 .1600 .0900 12.7000

40 10 92 1.0900 1.1600 .2500 .0800 14.6000

RATED SPEED "Nominal Data"

GEN PWR EKW

PERCENT LOAD

ENGINE POWER

BHP

TOTAL NOX (AS

NO2) LB/HR

TOTAL CO

LB/HR

TOTAL HC

LB/HR

TOTAL CO2

LB/HR

PART MATTER

LB/HR

OXYGEN IN

EXHAUST PERCENT

400 100 619 4.7600 .4700 .0600 694.7 .0500 10.1000

300 75 467 2.3600 1.5700 .0800 559.6 .0500 11.2000

200 50 319 1.4200 1.9100 .1100 412.7 .0600 12.0000

100 25 179 1.4000 .7500 .0800 233.3 .0500 12.7000

40 10 92 .9000 .6200 .1300 138.1 .0400 14.6000



Altitude Capability Data(Corrected Power Altitude Capability)

Ambient Operating Temp. 50 F 68 F 86 F 104 F 122 F NORMAL

A l t i t u d e

0 F 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp

984.25 F 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp

1,640.42 F 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp

3,280.84 F 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp 619.55 hp

4,921.26 F 619.55 hp 619.55 hp 619.55 hp 610.16 hp 591.39 hp 619.55 hp

6,561.68 F 619.55 hp 612.85 hp 592.73 hp 573.96 hp 556.52 hp 619.55 hp

8,202.1 F 596.75 hp 576.64 hp 557.86 hp 539.09 hp 523 hp 587.37 hp

9,842.52 F 560.55 hp 540.43 hp 523 hp 506.91 hp 490.81 hp 557.86 hp

10,498.69 F 545.8 hp 527.02 hp 509.59 hp 493.5 hp 478.74 hp 547.14 hp

The powers listed above and all the Powers displayed are Corrected Powers

Identification Reference and Notes

Engine Arrangement: 2729743 Lube Oil Press @ Rated Spd(PSI): --

Effective Serial No: FSE00001 Piston Speed @ Rated Eng SPD(FT/Min): 2,027.6

Primary Engine Test Spec: 0K6279 Max Operating Altitude(FT): 6,561.7

Performance Parm Ref: TM5739 PEEC Elect Control Module RefPerformance Data Ref: DM8151 PEEC Personality Cont Mod RefAux Coolant Pump Perf Ref:Cooling System Perf Ref: Turbocharger Model GTA5518BS

Certification Ref: EPA TIER 3 Fuel Injector

Certification Year: 2006 Timing-Static (DEG): --

Compression Ratio: 16.1 Timing-Static Advance (DEG): --

Combustion System: DI Timing-Static (MM): --

Aftercooler Temperature (F): 120 Unit Injector Timing (MM): --

Crankcase Blowby Rate(CFH): -- Torque Rise (percent) --

Fuel Rate (Rated RPM) No Load(Gal/HR): -- Peak Torque Speed RPM --

Lube Oil Press @ Low Idle Spd(PSI): -- Peak Torque (LB/FT): --



Reference Number: DM8151

EPA TIER-3 2005----D7EPA STAT EMERC 2011----P4

Parameters Reference: TM5739 GEN SET - PACKAGED - DIESEL

TOLERANCES: AMBIENT AIR CONDITIONS AND FUEL USED WILL AFFECT THESE VALUES. EACH OF THE VALUES MAY VARY IN ACCORDANCE WITH THE FOLLOWING TOLERANCES.

T4i Tolerance Exceptions C15: Power Tolerance +4% , -0% C27: Power Tolerance +0% , -4% CONDITIONS: ENGINE PERFORMANCE IS CORRECTED TO INLET AIR STANDARD CONDITIONS OF 99 KPA (29.31 IN HG) AND 25 DEG C (77 DEG F). THESE VALUES CORRESPOND TO THE STANDARD ATMOSPHERIC PRESSURE AND TEMPERATURE IN ACCORDANCE WITH SAE J1349. ALSO INCLUDED IS A CORRECTION TO STANDARD FUEL GRAVITY OF 35 DEGREES API HAVING A LOWER HEATING VALUE OF 42,780 KJ/KG (18,390 BTU/LB) WHEN USED AT 29 DEG C (84.2 DEG F) WHERE THE DENSITY IS 838.9 G/L (7.002 LB/GAL). THE CORRECTED PERFORMANCE VALUES SHOWN FOR CATERPILLAR ENGINES WILL APPROXIMATE THE VALUES OBTAINED WHEN THE OBSERVED PERFORMANCE DATA IS CORRECTED TO SAE J1349, ISO 3046-2 & 8665 & 2288 & 9249 & 1585, EEC 80/1269 AND DIN70020 STANDARD REFERENCE CONDITIONS. ENGINES ARE EQUIPPED WITH STANDARD ACCESSORIES; LUBE OIL, FUEL PUMP AND JACKET WATER PUMP. THE POWER REQUIRED TO DRIVE AUXILIARIES MUST BE DEDUCTED FROM THE GROSS OUTPUT TO ARRIVE AT THE NET POWER AVAILABLE FOR THE EXTERNAL (FLYWHEEL) LOAD. TYPICAL AUXILIARIES INCLUDE COOLING FANS, AIR COMPRESSORS, AND CHARGING ALTERNATORS. RATINGS MUST BE REDUCED TO COMPENSATE FOR ALTITUDE AND/OR AMBIENT TEMPERATURE CONDITIONS ACCORDING TO THE APPLICABLE DATA SHOWN ON

Power +/- 3%

Exhaust Stack Temperature +/- 8%

Generator Power +/- 5%

Inlet Airflow +/- 5%

Intake Manifold Pressure-gage +/- 10%

Exhaust Flow +/- 6%

Specific Fuel Consumption +/- 3%

Fuel Rate +/- 5%

Heat Rejection +/- 5%

Heat Rejection - Exhaust Only +/- 10%



THE PERFORMANCE DATA SET. ALTITUDE: ALTITUDE CAPABILITY - THE RECOMMENDED REDUCED POWER VALUES FOR SUSTAINED ENGINE OPERATION AT SPECIFIC ALTITUDE LEVELS AND AMBIENT TEMPERATURES. COLUMN "N" DATA - THE FLYWHEEL POWER OUTPUT AT NORMAL AMBIENT TEMPERATURE. AMBIENT TEMPERATURE - TO BE MEASURED AT THE AIR CLEANER AIR INLET DURING NORMAL ENGINE OPERATION. NORMAL TEMPERATURE - THE NORMAL TEMPERATURE AT VARIOUS SPECIFIC ALTITUDE LEVELS IS FOUND ON TM2001. THE GENERATOR POWER CURVE TABULAR DATA REPRESENTS THE NET ELECTRICAL POWER OUTPUT OF THE GENERATOR. GENERATOR SET RATINGS EMERGENCY STANDBY POWER (ESP) OUTPUT AVAILABLE WITH VARYING LOAD FOR THE DURATION OF AN EMERGENCY OUTAGE. AVERAGE POWER OUTPUT IS 70% OF THE ESP RATING. TYPICAL OPERATION IS 50 HOURS PER YEAR, WITH MAXIMUM EXPECTED USAGE OF 200 HOURS PER YEAR. STANDBY POWER RATING OUTPUT AVAILABLE WITH VARYING LOAD FOR THE DURATION OF AN EMERGENCY OUTAGE. AVERAGE POWER OUTPUT IS 70% OF THE STANDBY POWER RATING. TYPICAL OPERATION IS 200 HOURS PER YEAR, WITH MAXIMUM EXPECTED USAGE OF 500 HOURS PER YEAR. PRIME POWER RATING OUTPUT AVAILABLE WITH VARYING LOAD FOR AN UNLIMITED TIME. AVERAGE POWER OUTPUT IS 70% OF THE PRIME POWER RATING. TYPICAL PEAK DEMAND IS 100% OF PRIME RATED EKW WITH 10% OVERLOAD CAPABILITY FOR EMERGENCY USE FOR A MAXIMUM OF 1 HOUR IN 12. OVERLOAD OPERATION CANNOT EXCEED 25 HOURS PER YEAR. CONTINUOUS POWER RATING OUTPUT AVAILABLE WITH NON-VARYING LOAD FOR AN UNLIMITED TIME. AVERAGE POWER OUTPUT IS 70-100% OF THE CONTINUOUS POWER RATING. TYPICAL PEAK DEMAND IS 100% OF CONTINUOUS RATED EKW FOR 100% OF OPERATING HOURS. SOUND DEFINITIONS: Sound Power : DM8702 Sound Pressure : TM7080

Date Released : 03/14/12

Caterpillar Confidential: GreenContent Owner: Shane GillesWeb Master(s): PSG Web Based Systems SupportCurrent Date: Monday, August 06, 2012 1:35:08 PM



air emission permit no. 16300010-005 is issued to newport ... · losses, tank roof landing events,...

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