APPENDIX 10.2.5 

PREVENTION OF SIGNIFICANT DETERIORATION 

PERMIT APPLICATION 

 
APPLICATION FOR AIR CONSTRUCTION PERMIT/ 

GREENHOUSE GAS PREVENTION OF SIGNIFICANT 

DETERIORATION PERMIT 

 
Department of

Environmental Protection

Division of Air Resource Management 

APPLICATION FOR AIR PERMIT - LONG FORM 

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I. APPLICATION INFORMATION 

Air Construction Permit – Use this form to apply for an air construction permit: 

 For any required purpose at a facility operating under a federally enforceable state air operation 

permit (FESOP) or Title V air operation permit; 

 For a proposed project subject to prevention of significant deterioration (PSD) review, nonattainment 

new source review, or maximum achievable control technology (MACT); 

 To assume a restriction on the potential emissions of one or more pollutants to escape a requirement 

such as PSD review, nonattainment new source review, MACT, or Title V; or 

 To establish, revise, or renew a plantwide applicability limit (PAL). 

Air Operation Permit – Use this form to apply for: 

 An initial federally enforceable state air operation permit (FESOP); or 

 An initial, revised, or renewal Title V air operation permit. 

To ensure accuracy, please see form instructions. 

Identification of Facility

1. Facility Owner/Company Name: Florida Power & Light Company

2. Site Name: Port Everglades Plant

3. Facility Identification Number: 0110036

4. Facility Location... 

 Street Address or Other Locator: 8100 Eisenhower Boulevard

 City: Fort Lauderdale County: Broward Zip Code: 33316

5. Relocatable Facility? 

 Yes No 

6. Existing Title V Permitted Facility? 

 Yes No 

Application Contact

1. Application Contact Name: Barbara Linkiewicz, Director of Environmental Licensing

2. Application Contact Mailing Address... 

 Organization/Firm: Florida Power & Light Company

 Street Address: 700 Universe Blvd. JES/JB

 City: Juno Beach State: Florida Zip Code: 33408

3. Application Contact Telephone Numbers... 

 Telephone: (561) 691-7518 ext. Fax: (561) 691-7070

4. Application Contact E-mail Address: Barbara.P.Linkiewicz@FPL.com

Application Processing Information (DEP Use)

1. Date of Receipt of Application: 3. PSD Number (if applicable): 

2. Project Number(s): 4. Siting Number (if applicable): 
APPLICATION INFORMATION 

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Purpose of Application

This application for air permit is being submitted to obtain: (Check one)

Air Construction Permit 

 Air construction permit. 

 Air construction permit to establish, revise, or renew a plantwide applicability limit (PAL). 

 Air construction permit to establish, revise, or renew a plantwide applicability limit (PAL), 

and separate air construction permit to authorize construction or modification of one or 

more emissions units covered by the PAL. 

Air Operation Permit 

 Initial Title V air operation permit. 

 Title V air operation permit revision. 

 Title V air operation permit renewal. 

 Initial federally enforceable state air operation permit (FESOP) where professional 

engineer (PE) certification is required. 

 Initial federally enforceable state air operation permit (FESOP) where professional 

engineer (PE) certification is not required. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit 

(Concurrent Processing) 

 Air construction permit and Title V permit revision, incorporating the proposed project. 

 Air construction permit and Title V permit renewal, incorporating the proposed project. 

Note: By checking one of the above two boxes, you, the applicant, are 

requesting concurrent processing pursuant to Rule 62-213.405, F.A.C. In 

such case, you must also check the following box: 

 I hereby request that the department waive the processing time 

requirements of the air construction permit to accommodate the 

processing time frames of the Title V air operation permit. 

Application Comment

Application for an air construction permit to modernize the existing Port Everglades 

Plant Units 1 through 4 to a 3-on-1 combined-cycle facility. The attached Air Report 

provides detailed information regarding the proposed project. The combustion turbines 

(CTs) being considered for this application include the Mitsubishi Power Systems (MPS) 

“J” CTs and the Siemens Power Generation, Inc. “H” CTs. 

The Project will be subject to PSD review by EPA for Greenhouse Gas (GHG) emissions 

only. The maximum potential emissions estimated for all other regulated pollutants are 

less than the PSD significant emission rates and are not subject to PSD review by FDEP.
APPLICATION INFORMATION 

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Scope of Application

Emissions 

Unit ID

Number 

Description of Emissions Unit

Air 

Permit 

Type 

Air Permit 

Processing 

Fee

1A - 1C Three MPS 501J CTs/HRSGs AC1A 

 - OR - 

1A - 1C Three Siemens H CTs/HRSGs AC1A 

 - AND - 

2 Auxiliary Boiler AC1A 

3 Fuel Gas Heater AC1A 

4 Emergency Diesel Generators AC1A 

5 Compressor Station AC1A 

6 Fire Pump Engine AC1A 

7 Temporary Construction Boilers AC1A 

 

 

 

 

Application Processing Fee

Check one: Attached - Amount: $ Not Applicable

APPLICATION INFORMATION 

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Application Responsible Official Certification

Complete if applying for an initial, revised, or renewal Title V air operation permit or 

concurrent processing of an air construction permit and revised or renewal Title V air 

operation permit. If there are multiple responsible officials, the “application responsible 

official” need not be the “primary responsible official.” 

1. Application Responsible Official Name: 

 

2. Application Responsible Official Qualification (Check one or more of the following 

options, as applicable): 

For a corporation, the president, secretary, treasurer, or vice-president of the corporation in 

charge of a principal business function, or any other person who performs similar policy or 

decision-making functions for the corporation, or a duly authorized representative of such 

person if the representative is responsible for the overall operation of one or more 

manufacturing, production, or operating facilities applying for or subject to a permit under 

Chapter 62-213, F.A.C.

For a partnership or sole proprietorship, a general partner or the proprietor, respectively. 

For a municipality, county, state, federal, or other public agency, either a principal executive 

officer or ranking elected official. 

The designated representative at an Acid Rain source or CAIR source.

3. Application Responsible Official Mailing Address... 

 Organization/Firm: 

Street Address: 

City: State: Zip Code: 

4. Application Responsible Official Telephone Numbers... 

 Telephone: ( ) ext. Fax: ( ) 

5. Application Responsible Official E-mail Address: 

6. Application Responsible Official Certification: 

I, the undersigned, am a responsible official of the Title V source addressed in this air permit 

application. I hereby certify, based on information and belief formed after reasonable inquiry, 

that the statements made in this application are true, accurate and complete and that, to the best 

of my knowledge, any estimates of emissions reported in this application are based upon 

reasonable techniques for calculating emissions. The air pollutant emissions units and air 

pollution control equipment described in this application will be operated and maintained so as 

to comply with all applicable standards for control of air pollutant emissions found in the 

statutes of the State of Florida and rules of the Department of Environmental Protection and 

revisions thereof and all other applicable requirements identified in this application to which 

the Title V source is subject. I understand that a permit, if granted by the department, cannot 

be transferred without authorization from the department, and I will promptly notify the 

department upon sale or legal transfer of the facility or any permitted emissions unit. Finally, I 

certify that the facility and each emissions unit are in compliance with all applicable 

requirements to which they are subject, except as identified in compliance plan(s) submitted 

with this application. 

 

 Signature Date 

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II. FACILITY INFORMATION 

A. GENERAL FACILITY INFORMATION 

Facility Location and Type

1. Facility UTM Coordinates... 

 Zone 17 East (km) 587.38

North (km) 2885.25

2. Facility Latitude/Longitude... 

 Latitude (DD/MM/SS) 26/05/08

 Longitude (DD/MM/SS) 80/07/31

3. Governmental 

 Facility Code: 

O

4. Facility Status 

 Code: 

A

5. Facility Major 

 Group SIC Code: 

49

6. Facility SIC(s): 

4911

 

7. Facility Comment : 

 

 

Facility Contact

1. Facility Contact Name: 

Rudy Sanchez, Regional Plant General Manager

2. Facility Contact Mailing Address... 

 Organization/Firm: Florida Power & Light Company

Street Address: 8100 Eisenhower Boulevard

City: Fort Lauderdale State: FL Zip Code: 33316

3. Facility Contact Telephone Numbers: 

 Telephone: (954) 527-3601 ext. Fax: (954) 527-3636

4. Facility Contact E-mail Address: rudy.sanchez@fpl.com

Facility Primary Responsible Official

Complete if an “application responsible official” is identified in Section I that is not the 

facility “primary responsible official.” 

1. Facility Primary Responsible Official Name: 

 

2. Facility Primary Responsible Official Mailing Address... 

 Organization/Firm: 

Street Address: 

City: State: Zip Code: 

3. Facility Primary Responsible Official Telephone Numbers... 

 Telephone: ( ) ext. Fax: ( ) 

4. Facility Primary Responsible Official E-mail Address: 
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Facility Regulatory Classifications

Check all that would apply following completion of all projects and implementation of all 

other changes proposed in this application for air permit. Refer to instructions to 

distinguish between a “major source” and a “synthetic minor source.” 

1. Small Business Stationary Source Unknown 

2. Synthetic Non-Title V Source 

3. Title V Source 

4. Major Source of Air Pollutants, Other than Hazardous Air Pollutants (HAPs) 

5. Synthetic Minor Source of Air Pollutants, Other than HAPs 

6. Major Source of Hazardous Air Pollutants (HAPs) 

7. Synthetic Minor Source of HAPs 

8. One or More Emissions Units Subject to NSPS (40 CFR Part 60) 

9. One or More Emissions Units Subject to Emission Guidelines (40 CFR Part 60) 

10. One or More Emissions Units Subject to NESHAP (40 CFR Part 61 or Part 63) 

11. Title V Source Solely by EPA Designation (40 CFR 70.3(a)(5)) 

12. Facility Regulatory Classifications Comment: 

 

The Port Everglades Plant remains a major source of HAPs due to the combined emissions 

of PEEC and the 12 existing gas turbines. The proposed project is subject to PSD review by 

EPA for Greenhouse Gas emissions only.
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List of Pollutants Emitted by Facility

1. Pollutant Emitted 2. Pollutant Classification 3. Emissions Cap 

 [Y or N]? 

PM A N

PM10 A N

VOC A N

SO2 A N

NOx A N

CO A N

 

 

 

 

 

 

 

 

 
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B. EMISSIONS CAPS 

Facility-Wide or Multi-Unit Emissions Caps

1. Pollutant 

 Subject to 

 Emissions

 Cap 

2. Facility- 

 Wide Cap 

 [Y or N]? 

 (all units) 

3. Emissions 

 Unit ID’s 

 Under Cap 

 (if not all units) 

4. Hourly 

 Cap 

 (lb/hr) 

5. Annual 

 Cap 

 (ton/yr) 

6. Basis for 

 Emissions 

 Cap 

 

 

 

 

 

 

 

 

 

 

 

 

 

7. Facility-Wide or Multi-Unit Emissions Cap Comment: 

 
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C. FACILITY ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Facility Plot Plan: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought) 

 Attached, Document ID: See Air Report Previously Submitted, Date: 

2. Process Flow Diagram(s): (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought) 

 Attached, Document ID: See Air Report Previously Submitted, Date: 

3. Precautions to Prevent Emissions of Unconfined Particulate Matter: (Required for all permit 

applications, except Title V air operation permit revision applications if this information was 

submitted to the department within the previous five years and would not be altered as a result of 

the revision being sought) 

 Attached, Document ID: See Air Report Previously Submitted, Date: 

Additional Requirements for Air Construction Permit Applications

1. Area Map Showing Facility Location: 

 Attached, Document ID: See Air Report Not Applicable 

(existing permitted facility)

2. Description of Proposed Construction, Modification, or Plantwide Applicability Limit 

(PAL): 

 Attached, Document ID: See Air Report

3. Rule Applicability Analysis: 

 Attached, Document ID: See Air Report

4. List of Exempt Emissions Units: 

 Attached, Document ID: Not Applicable (no exempt units at facility)

5. Fugitive Emissions Identification: 

 Attached, Document ID: Not Applicable 

6. Air Quality Analysis (Rule 62-212.400(7), F.A.C.): 

 Attached, Document ID: Not Applicable 

7. Source Impact Analysis (Rule 62-212.400(5), F.A.C.): 

 Attached, Document ID: Not Applicable 

8. Air Quality Impact since 1977 (Rule 62-212.400(4)(e), F.A.C.): 

 Attached, Document ID: Not Applicable 

9. Additional Impact Analyses (Rules 62-212.400(8) and 62-212.500(4)(e), F.A.C.): 

 Attached, Document ID: Not Applicable 

10. Alternative Analysis Requirement (Rule 62-212.500(4)(g), F.A.C.): 

 Attached, Document ID: Not Applicable
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C. FACILITY ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for FESOP Applications

1. List of Exempt Emissions Units: 

 Attached, Document ID: Not Applicable (no exempt units at facility)

Additional Requirements for Title V Air Operation Permit Applications

1. List of Insignificant Activities: (Required for initial/renewal applications only)

 Attached, Document ID: Not Applicable (revision application) 

2. Identification of Applicable Requirements: (Required for initial/renewal applications, and for 

revision applications if this information would be changed as a result of the revision being sought) 

 Attached, Document ID: 

 Not Applicable (revision application with no change in applicable requirements) 

3. Compliance Report and Plan: (Required for all initial/revision/renewal applications) 

 Attached, Document ID: 

Note: A compliance plan must be submitted for each emissions unit that is not in compliance with 

all applicable requirements at the time of application and/or at any time during application 

processing. The department must be notified of any changes in compliance status during 

application processing. 

4. List of Equipment/Activities Regulated under Title VI: (If applicable, required for 

initial/renewal applications only) 

 Attached, Document ID: 

 Equipment/Activities Onsite but Not Required to be Individually Listed 

 Not Applicable 

5. Verification of Risk Management Plan Submission to EPA: (If applicable, required for 

initial/renewal applications only) 

 Attached, Document ID: Not Applicable 

6. Requested Changes to Current Title V Air Operation Permit: 

 Attached, Document ID: Not Applicable 
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C. FACILITY ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Facilities Subject to Acid Rain, CAIR, or Hg Budget Program

1. Acid Rain Program Forms: 

Acid Rain Part Application (DEP Form No. 62-210.900(1)(a)): 

 Attached, Document ID: Previously Submitted, Date: 4/15/08

 Not Applicable (not an Acid Rain source) 

Phase II NOX Averaging Plan (DEP Form No. 62-210.900(1)(a)1.): 

 Attached, Document ID: Previously Submitted, Date: 

 Not Applicable 

New Unit Exemption (DEP Form No. 62-210.900(1)(a)2.): 

 Attached, Document ID: Previously Submitted, Date: 

 Not Applicable 

2. CAIR Part (DEP Form No. 62-210.900(1)(b)): 

 Attached, Document ID: Previously Submitted, Date: 5/27/08

 Not Applicable (not a CAIR source) 

Additional Requirements Comment

FPL will provide the appropriate acid rain and CAIR forms to change the existing plant to 

the 3-on-1 combined cycle unit. 
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a single 

process or production unit, or activity, which produces one or more air pollutants and 

which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

 Three Mitsubishi Power Systems (MPS) 501G CT/HRSGs or Siemens H CTs or equivalent

3. Emissions Unit Identification Number: 5A, 5B, 5C

4. Emissions Unit 

 Status Code: 

 C

5. Commence 

 Construction 

 Date: 

 2013 

6. Initial Startup 

 Date: 

 2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

 49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Mitsubishi Power Systems (MPS) or Siemons or equivalent Model Number: 

MPS "J" or Siemens "H" CTs or equivalent

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

Combined cycle unit will have a nominal capacity of 1,250 MW consisting of 3 CT/HRSG 

trains.
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs 

Emissions Unit Control Equipment/Method: Control 1 of 2

1. Control Equipment/Method Description: 

Natural Gas: Combined Cycle - SCR

2. Control Device or Method Code: 139

Emissions Unit Control Equipment/Method: Control 2 of 2

1. Control Equipment/Method Description: 

 Distillate Fuel Oil: 

 Water Injection 

 Combined Cycle - SCR 

2. Control Device or Method Code: 25, 28

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 8,760 hours/year 

6. Operating Capacity/Schedule Comment: 

See Tables A-1-501J and B-1-SH for maximum heat input when firing natural gas; and 

Tables A-7-501J and B-7-SH for maximum heat input when firing ultra low sulfur light oil.
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

1

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

Exhausts through the HRSG stack.

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

V

6. Stack Height: 

149 feet 

7. Exit Diameter: 

 22 feet 

8. Exit Temperature: 

See Air ReportF 

9. Actual Volumetric Flow Rate: 

See Air Report acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Tables 2-1A, 2-2A, 2-1B, and 2-2B for the stack parameters associated with each CT 

when firing natural gas and ultra low sulfur light oil.
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 2

1. Segment Description (Process/Fuel Type): 

Distillate (No. 2) Fuel Oil [Ultra Low Sulfur (0.0015%) Light Oil]

2. Source Classification Code (SCC): 

20100101

3. SCC Units: 

1,000 Gallons Used

4. Maximum Hourly Rate: 

19.3

5. Maximum Annual Rate: 

17,618

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

0.0015

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

131

10. Segment Comment: 

Million British thermal units (Btu) per SCC unit = 130.5 (rounded to 131). Based on 

7.1 pounds per gallon (lb/gal); LHV = 18,387 Btu/lb ISO conditions. Max hourly rate 

based on 35°F, max annual rate based on 75°F and 1,000 hours per year (hr/yr) 

operation. Based on Siemens H Units per CT. See Air Permit Application Report for 

further details on MPS J and Siemens H models.

Segment Description and Rate: Segment 2 of 2

1. Segment Description (Process/Fuel Type): 

Natural Gas

2. Source Classification Code (SCC): 

20100201

3. SCC Units: 

Million cubic feet

4. Maximum Hourly Rate: 

2.98

5. Maximum Annual Rate: 

24,232

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

918

10. Segment Comment: 

Based on 918 Btu/cf (LHV). Max hourly rate based on 35oF. Max annual rate based on 

75oF and 8,760 hr/yr operation. Based on MPS Units. Maximum sulfur content 2 

grains/100 scf See Air Permit Application Report.
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EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

PM EL

PM10 EL

SO2 EL

NOX 25, 28, 139 EL

CO EL

VOC EL

 

 

 

 

 

 

 

 

 

 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [1] of [6] 

Units 1A-1C, CT/HRSGs Particulate Matter Total - PM

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter Total - PM

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [1] of [6] 

Units 1A-1C, CT/HRSGs Particulate Matter Total - PM

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [2] of [6] 

Units 1A-1C, CT/HRSGs Particulate Matter - PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [2] of [6] 

Units 1A-1C, CT/HRSGs Particulate Matter - PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [3] of [6] 

Units 1A-1C, CT/HRSGs Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [3] of [6] 

Units 1A-1C, CT/HRSGs Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [4] of [6] 

Units 1A-1C, CT/HRSGs Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [4] of [6] 

Units 1A-1C, CT/HRSGs Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [5] of [6] 

Units 1A-1C, CT/HRSGs Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [5] of [6] 

Units 1A-1C, CT/HRSGs Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [6] of [6] 

Units 1A-1C, CT/HRSGs Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

 See Air Report lb/hour See Air Report tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: See Air Report

 Reference: 

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Appendix C for baseline emissions. Tables 2-1A, 2-2A, and 2-3A for MPS 

501J; Tables 2-1B, 2-2B, and 2-3B for Siemens H; and Appendices A and B.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [1] Page [6] of [6] 

Units 1A-1C, CT/HRSGs Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

See Air Report; Table 4-1

4. Equivalent Allowable Emissions: 

See Air Report lb/hour See Air Report tons/year 

5. Method of Compliance: 

See Air Report, Table 4-1

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 2

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C. requires 20 percent opacity. Excess emissions 

provided by Rule 62-210.700(1).

Visible Emissions Limitation: Visible Emissions Limitation 2 of 2

1. Visible Emissions Subtype: 

VE10

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 10 % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

Proposed as emission limit for PM/PM10.
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor 1 of 2

1. Parameter Code: 

EM

2. Pollutant(s): 

NOX

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

CEM required pursuant to 40 CFR 75. NOx monitoring includes diluent monitor (O2 or CO2).

Continuous Monitoring System: Continuous Monitor 2 of 2

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 35 01/2012 

EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: Not Applicable 
Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU1_CTs.docx 

Effective: 03/11/2010 36 01/2012 

EMISSIONS UNIT INFORMATION 

Section [1] 

Units 1A-1C, CT/HRSGs

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: See Air Report Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: See Air Report Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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Effective: 03/11/2010 15 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

 Auxiliary Boiler 

3. Emissions Unit Identification Number: 2

4. Emissions Unit 

 Status Code: 

 C

5. Commence 

 Construction 

 Date: 

 2013 

6. Initial Startup 

 Date: 

 2015–2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

 49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Nebraska Boiler or equivalent Model Number: 

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

 
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler 

Emissions Unit Control Equipment/Method: Control 1 of 1

1. Control Equipment/Method Description: 

Low NOX burners

2. Control Device or Method Code: 205

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 99.77 million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 2,000 hours/year 

6. Operating Capacity/Schedule Comment: 

 
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

 

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

 

6. Stack Height: 

60 feet 

7. Exit Diameter: 

2.75 Feet 

8. Exit Temperature: 

296F 

9. Actual Volumetric Flow Rate: 

29,325 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Table 2-4 in Air Permit Application Report.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

Natural gas

2. Source Classification Code (SCC): 

 

3. SCC Units: 

MMscf

4. Maximum Hourly Rate: 

0.098

5. Maximum Annual Rate: 

195.6

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

1,020

10. Segment Comment: 

Maximum annual rate based on 2,000 hr/yr operation.

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

PM Fuel Quality EL

PM10 Fuel Quality EL

SO2 Fuel Quality EL

NOX 205 EL

CO Good Combustion EL

VOC Good Combustion EL

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [1] of [6] 

Auxiliary Boiler Particulate Matter Total - PM

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter Total - PM

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.74 lb/hour 0.74 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0075 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0075 lb/MMBtu x 99.77 MMBtu/hr = 0.74 lb/hr 

0.74 lb/hr x 2,000 hr x ton/2,000 lb = 0.74 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [1] of [6] 

Auxiliary Boiler Particulate Matter Total - PM

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% Opacity

4. Equivalent Allowable Emissions: 

0.74 lb/hour 0.74 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [2] of [6] 

Auxiliary Boiler Particulate Matter - PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.74 lb/hour 0.74 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0075 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0075 lb/MMBtu x 99.77 MMBtu/hr = 0.74 lb/hr 

 0.74 lb/hr x 2,000 hr x ton/2,000 lb = 0.74 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [2] of [6] 

Auxiliary Boiler Particulate Matter - PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% Opacity

4. Equivalent Allowable Emissions: 

0.70 lb/hour 0.17 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [3] of [6] 

Auxiliary Boiler Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.56 lb/hour 0.56 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 2 grains S/100 scf gas

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

2 grains S/100 scf x 64/32 (MW SO2/S) x 1 lb/7,000 gr x 97,814 scf/hr x 1/100 scf = 0.56 lb/hr 

0.56 lb/hr x 2,000 hr/2,000 lb = 0.56 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [3] of [6] 

Auxiliary Boiler Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

2 grains S/100 scf gas

4. Equivalent Allowable Emissions: 

0.56 lb/hour 0.56 tons/year 

5. Method of Compliance: 

Fuel Sampling and Analysis

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [4] of [6] 

Auxiliary Boiler Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

4.99 lb/hour 4.99 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.050 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.050 lb/MMBtu x 99.77 MMBtu/hr = 4.99 lb/hr 

4.99 lb/hr x 2,000 hr x ton/2,000 lb = 4.99 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [4] of [6] 

Auxiliary Boiler Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.050 lb/MMBtu

4. Equivalent Allowable Emissions: 

4.99 lb/hour 4.99 tons/year 

5. Method of Compliance: 

EPA Method 7e

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [5] of [6] 

Auxiliary Boiler Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

7.98 lb/hour 7.98 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.080 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.08 lb/MMBtu x 99.77 MMBtu/hr = 7.98 lb/hr 

 7.98 lb/hr x 2,000 hr x ton/2,000 lb = 7.98 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [5] of [6] 

Auxiliary Boiler Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.080 lb/MMBtu

4. Equivalent Allowable Emissions: 

7.98 lb/hour 7.98 tons/year 

5. Method of Compliance: 

EPA Method 10

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [6] of [6] 

Auxiliary Boiler Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.54 lb/hour 0.54 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0054 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0054 lb/MMBtu x 99.77 MMBtu/hr = 0.54 lb/hr 

0.54 lb/hr x 2,000 hr x ton/2,000 lb = 0.54 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] Page [6] of [6] 

Auxiliary Boiler Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.005 lb/MMBtu

4. Equivalent Allowable Emissions: 

0.54 lb/hour 0.54 tons/year 

5. Method of Compliance: 

EPA Method 25A; Initial only

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 2

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C., requires 20% opacity. Excess emissions provided 

by Rule 62-210.700(1), F.A.C.

Visible Emissions Limitation: Visible Emissions Limitation 2 of 2

1. Visible Emissions Subtype: 

VE10

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 10 % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

Proposed as emission limit for PM/PM10.
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 35 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 36 01/2012 

EMISSIONS UNIT INFORMATION 

Section [2] 

Auxiliary Boiler

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: See Air Report Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: See Air Report Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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Effective: 03/11/2010 15 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

Natural Gas Fuel Heater(s)

3. Emissions Unit Identification Number: 3

4. Emissions Unit 

 Status Code: 

C

5. Commence 

 Construction 

 Date: 

2013 

6. Initial Startup 

 Date: 

2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Hanover Compression Company or equivalent Model Number: 

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

See Air Permit application report.
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 9.9 million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 8,760 hours/year 

6. Operating Capacity/Schedule Comment: 

 
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

1

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

V

6. Stack Height: 

30 feet 

7. Exit Diameter: 

1 Feet 

8. Exit Temperature: 

500F 

9. Actual Volumetric Flow Rate: 

4,950 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Table 2-6 in Air Permit Application Report.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

Natural gas

2. Source Classification Code (SCC): 

 

3. SCC Units: 

1,000,000 SCF

4. Maximum Hourly Rate: 

0.01

5. Maximum Annual Rate: 

85.0

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

1,020

10. Segment Comment: 

Maximum annual rate based on 8,760 hr/yr operation.

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

CO EL

PM/PM10 Fuel Quality EL

NOX EL

SO2 Fuel Quality EL

VOC EL

 

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [1] of [5] 

Fuel Gas Heater Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.82 lb/hour 3.57 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.082 lb/MMBtu

 Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.082 lb/MMBtu x 9.9 MMBtu/hr = 0.82 lb/hr 

0.82 lb/hr x 8,760 hr x ton/2,000 lb = 3.57 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [1] of [5] 

Fuel Gas Heater Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.082 lb/MMBtu

4. Equivalent Allowable Emissions: 

0.82 lb/hour 3.57 tons/year 

5. Method of Compliance: 

Manufacturer Certification

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [2] of [5] 

Fuel Gas Heater Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.97 lb/hour 4.25 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.098 lb/MMBtu

 Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.098 lb/MMBtu x 9.9 MMBtu/hr = 0.97 lb/hr 

0.97 lb/hr x 8,760 hr x ton/2,000 lb = 4.25 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [2] of [5] 

Fuel Gas Heater Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.098 lb/MMBtu

4. Equivalent Allowable Emissions: 

0.97 lb/hour 4.25 tons/year 

5. Method of Compliance: 

Manufacturer Certification

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [3] of [5] 

Fuel Gas Heater Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.055 lb/hour 0.24 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 2 grains S/100 scf gas

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

2 grains S/100 scf x 64/32 (MW SO2/S) x 1 lb/7,000 gr x 9,706 scf/hr x 1/100 scf = 0.055 lb/hr 

 0.055 lb/hr x 8,760 hr x ton/2,000 lb = 0.24 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [3] of [5] 

Fuel Gas Heater Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

2 grains S/100 scf

4. Equivalent Allowable Emissions: 

0.055 lb/hour 0.24 tons/year 

5. Method of Compliance: 

Fuel vendor information

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [4] of [5] 

Fuel Gas Heater Particulate Matter - PM/PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM/PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.074 lb/hour 0.32 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0075 lb/MMBtu

 Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 0.0075 lb/MMBtu x 9.9 MMBtu/hr = 0.074 lb/hr 

 0.074 lb/hr x 8,760 hr x ton/2,000 lb = 0.32 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [4] of [5] 

Fuel Gas Heater Particulate Matter - PM/PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% opacity

4. Equivalent Allowable Emissions: 

0.074 lb/hour 0.32 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [5] of [5] 

Fuel Gas Heater Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.053 lb/hour 0.23 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0054 lb/MMBtu

 Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0054 lb/MMBtu x 9.9 MMBtu/hr = 0.053 lb/hr 

0.053 lb/hr x 8,760 hr x ton/2,000 lb = 0.23 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [3] Page [5] of [5] 

Fuel Gas Heater Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.0054 lb/MMBtu

4. Equivalent Allowable Emissions: 

0.053 lb/hour 0.23 tons/year 

5. Method of Compliance: 

Natural gas

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 1

1. Visible Emissions Subtype: 

VE10

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 10 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: Excess emissions provided by Rule 62-210.700.

Visible Emissions Limitation: Visible Emissions Limitation of 

1. Visible Emissions Subtype: 

 

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: 

5. Visible Emissions Comment: 
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [3] 

Fuel Gas Heater

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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Effective: 03/11/2010 15 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

Emergency generators (2) to supply power in the event power is not available.

3. Emissions Unit Identification Number: 4

4. Emissions Unit 

 Status Code: 

C

5. Commence 

 Construction 

 Date: 

2013 

6. Initial Startup 

 Date: 

2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Caterpillar or equivalent Model Number: 3516BTA or equivalent

10. Generator Nameplate Rating: 2.25 MW 

11. Emissions Unit Comment: 

Two 2,250-kW emergency generators, each with rating of 3,200 hp. Information based 

on Caterpillar, 2,250 kW Diesel Generator Set.
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator 

Emissions Unit Control Equipment/Method: Control 1 of 1

1. Control Equipment/Method Description: 

Good combustion practices - No. 2 fuel oil-fired.

2. Control Device or Method Code: N/A

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 21.01 million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 100 hours/year 

6. Operating Capacity/Schedule Comment: 

The emergency generators will normally be operated 1 to 2 hours per month for testing 

and maintenance. The emergency generators will meet the requirements of 40 CFR 60 

Subpart IIII.
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

1

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

V

6. Stack Height: 

30 feet 

7. Exit Diameter: 

1.0 Feet 

8. Exit Temperature: 

916F 

9. Actual Volumetric Flow Rate: 

17,463 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Table 2-5 in Air Permit Application Report.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

Diesel fuel combustion

2. Source Classification Code (SCC): 

 

3. SCC Units: 

1,000 gallons

4. Maximum Hourly Rate: 

0.153

5. Maximum Annual Rate: 

15.3

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

0.0015

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

137.7

10. Segment Comment: 

Maximum annual rate based on 100 hr/yr operation.

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

CO EL

PM/PM10 EL

NOX EL

SO2 Fuel Quality EL

VOC EL

 

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [1] of [5] 

Emergency Diesel Generator Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

60.0 lb/hour 3.0 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 8.5 grams per horsepower-hour (g/hp-hr)

Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

8.5 g/hp-hr x 3,200 hp x 1 lb/453.6 g = 60 lb/hr 

60 lb/hr x 100 hr x ton/2,000 lb = 3.0 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

 Emissions are for one generator.
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Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [1] of [5] 

Emergency Diesel Generator Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

8.5 g/hp-hr

4. Equivalent Allowable Emissions: 

60.0 lb/hour 3.0 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [2] of [5] 

Emergency Diesel Generator Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

48.7 lb/hour 2.4 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 6.9 g/hp-hr

Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

6.9 g/hp-hr x 3,200 hp x 1 lb/453.6 g = 48.7 lb/hr 

 48.7 lb/hr x 100 hr x ton/2,000 lb = 2.4 TPY 

11. Potential, Fugitive, and Actual Emissions Comment: 

 Emissions are for one generator.
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [2] of [5] 

Emergency Diesel Generator Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

6.9 g/hp-hr

4. Equivalent Allowable Emissions: 

48.7 lb/hour 2.4 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [3] of [5] 

Emergency Diesel Generator Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.032 lb/hour 0.0016 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0015% S fuel oil

 Reference: FPL, 2011

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0015% S x 64/32 (MW SO2/S) x 7.06 lb/gal x 152.6 gal/hr = 0.032 lb/hr 

0.032 lb/hr x 100 hr x ton/2,000 lb = 0.0016 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one generator.
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [3] of [5] 

Emergency Diesel Generator Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.0015% S fuel oil

4. Equivalent Allowable Emissions: 

0.032 lb/hour 0.0016 tons/year 

5. Method of Compliance: 

Fuel vendor information

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [4] of [5] 

Emergency Diesel Generator Particulate Matter - PM/PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM/PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

2.8 lb/hour 0.14 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.4 g/hp-hr

Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.4 g/hp-hr x 3,200 hp x 1 lb/453.6 g = 2.8 lb/hr 

 2.8 lb/hr x 100 hr x ton/2,000 lb = 1.4 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one generator.
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [4] of [5] 

Emergency Diesel Generator Particulate Matter - PM/PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.4 g/hp-hr

4. Equivalent Allowable Emissions: 

2.8 lb/hour 0.14 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII Standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [5] of [5] 

Emergency Diesel Generator Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

7.1 lb/hour 0.35 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 1.0 g/hp-hr

Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

1.0 g/hp-hr x 3,200 hp x 1 lb/453.6 g = 7.1 lb/hr 

7.1 lb/hr x 100 hr x ton/2,000 lb = 0.35 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one generator.
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [4] Page [5] of [5] 

Emergency Diesel Generator Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

1.0 g/hp-hr

4. Equivalent Allowable Emissions: 

7.1 lb/hour 0.35 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII Standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 1

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C. requires 20 percent opacity. Excess emissions 

provided by Rule 62-210.700.

Visible Emissions Limitation: Visible Emissions Limitation of 

1. Visible Emissions Subtype: 

 

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: 

5. Visible Emissions Comment: 
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [4] 

Emergency Diesel Generator

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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Effective: 03/11/2010 15 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

Compressor Engines

3. Emissions Unit Identification Number: 5

4. Emissions Unit 

 Status Code: 

C

5. Commence 

 Construction 

 Date: 

2013 

6. Initial Startup 

 Date: 

2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Solar Turbines or equivalent Model Number: Centaur 50 or equivalent

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

Includes 3 natural gas-fired units, each rated at 5,514 hp at 75oF. Only 2 units will 

operate at any time. Based on emissions from a Solar Turbines Centaur 50.
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station 

Emissions Unit Control Equipment/Method: Control 1 of 1

1. Control Equipment/Method Description: 

Dry Low-NOX Combustion

2. Control Device or Method Code: 025

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 54.0 million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 8,760 hours/year 

6. Operating Capacity/Schedule Comment: 

Maximum heat input based on 75°F (HHV).
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

1

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

V

6. Stack Height: 

20.7 feet 

7. Exit Diameter: 

3.5 Feet 

8. Exit Temperature: 

969F 

9. Actual Volumetric Flow Rate: 

86,579 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Table 2-8 in the Air Permit Application Report; operating conditions based on 75°F.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

Natural gas

2. Source Classification Code (SCC): 

 

3. SCC Units: 

MMscf

4. Maximum Hourly Rate: 

0.0562

5. Maximum Annual Rate: 

454.4

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

1,041

10. Segment Comment: 

Fuel rates presented per unit. Maximum hourly and annual fuel rates based on 35°F and 

75°F, respectively. Maximum annual rate based on 8,760 hr/yr operation.

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

CO EL

PM/PM10 EL

NOX EL

SO2 EL

VOC EL

 

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [1] of [5] 

Compressor Station Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

3.22 lb/hour 12.8 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 25 ppmvd @ 15% O2

Reference: Manufacturer's specifications

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report; Table 2-8

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.
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Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [1] of [5] 

Compressor Station Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

25 ppmvd @ 15% O2

4. Equivalent Allowable Emissions: 

3.22 lb/hour 12.8 tons/year 

5. Method of Compliance: 

 Manufacturer's certification

6. Allowable Emissions Comment (Description of Operating Method): 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [2] of [5] 

Compressor Station Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

3.17 lb/hour 12.6 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 15 ppmvd @ 15% O2

Reference: Manufacturer's specifications

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report; Table 2-8

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [2] of [5] 

Compressor Station Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

15 ppmvd @ 15% O2

4. Equivalent Allowable Emissions: 

 3.17 lb/hour 12.6 tons/year 

5. Method of Compliance: 

Manufacturer's certification

6. Allowable Emissions Comment (Description of Operating Method): 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [3] of [5] 

Compressor Station Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.32 lb/hour 1.30 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 2 grains S/100 scf

 Reference: FPL, 2011

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report, Table 2-8.

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [3] of [5] 

Compressor Station Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

2 grains S/100 scf

4. Equivalent Allowable Emissions: 

0.32 lb/hour 1.30 tons/year 

5. Method of Compliance: 

Fuel vendor information

6. Allowable Emissions Comment (Description of Operating Method): 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [4] of [5] 

Compressor Station Particulate Matter - PM/PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM/PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.37 lb/hour 1.5 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0063 lb/MMBtu

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

 3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report; Table 2-8

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [4] of [5] 

Compressor Station Particulate Matter - PM/PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% Opacity

4. Equivalent Allowable Emissions: 

0.37 lb/hour 1.5 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [5] of [5] 

Compressor Station Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.92 lb/hour 3.6 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 12.5 ppmvd @ 15% O2

Reference: Manufacturer's specifications

7. Emissions 

 Method Code: 

 2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Air Report; Table 2-8; VOC emissions are assumed to be 50 percent of unburned 

hydrocarbon emissions.

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [5] Page [5] of [5] 

Compressor Station Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

12.5 ppmvd @ 15% O2

4. Equivalent Allowable Emissions: 

0.92 lb/hour 3.6 tons/year 

5. Method of Compliance: 

Manufacturer's certification

6. Allowable Emissions Comment (Description of Operating Method): 

Emissions presented per unit. Maximum hourly and annual emissions based on 35°F 

and 75°F, respectively.

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 2

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C. requires 20 percent opacity. Excess emissions 

provided by Rule 62-210.700. 

Visible Emissions Limitation: Visible Emissions Limitation 2 of 2

1. Visible Emissions Subtype: 

VE10

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 10 % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

Proposed for PM/PM10 emissions.
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [5] 

Compressor Station

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications – N/A

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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Effective: 03/11/2010 15 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

Diesel fire pump engine for emergency usage.

3. Emissions Unit Identification Number: 6

4. Emissions Unit 

 Status Code: 

C

5. Commence 

 Construction 

 Date: 

2013 

6. Initial Startup 

 Date: 

2016 

7. Emissions Unit 

 Major Group 

 SIC Code: 

49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: TBD Model Number: TBD

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

One diesel fire pump engine rated at 300 hp. Manufacturer and model number to be 

determined (TBD).
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine 

Emissions Unit Control Equipment/Method: Control 1 of 1

1. Control Equipment/Method Description: 

Good combustion practices - No. 2 fuel oil-fired.

2. Control Device or Method Code: N/A

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 2.32 million Btu/hr 

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 100 hours/year 

6. Operating Capacity/Schedule Comment: 

The diesel fire pump engine will normally be operated 1 to 2 hours per month for testing 

and maintenance. The fire pump engine will meet the requirements of 40 CFR 60 

Subpart IIII.
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

1

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

V

6. Stack Height: 

17 feet 

7. Exit Diameter: 

0.79 Feet 

8. Exit Temperature: 

744F 

9. Actual Volumetric Flow Rate: 

1,750 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

See Table 2-7 in Air Permit Application Report.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

Diesel fuel combustion

2. Source Classification Code (SCC): 

 

3. SCC Units: 

1,000 gallons

4. Maximum Hourly Rate: 

0.017

5. Maximum Annual Rate: 

1.69

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

0.0015

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

137.7

10. Segment Comment: 

Maximum annual rate based on 80 hr/yr operation.

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

CO EL

PM/PM10 EL

NOX EL

SO2 Fuel Quality EL

VOC EL

 

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [1] of [5] 

Diesel Fire Pump Engine Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

1.7 lb/hour 0.09 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 2.6 grams per horsepower-hour (g/hp-hr)

Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 2.6 g/hp-hr x 300 hp x 1 lb/453.6 g = 1.7 lb/hr 

 1.7 lb/hr x 100 hr/2,000 lb = 0.09 TPY 

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one engine.
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Effective: 03/11/2010 22 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [1] of [5] 

Diesel Fire Pump Engine Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

2.6 g/hp-hr

4. Equivalent Allowable Emissions: 

1.7 lb/hour 0.09 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [2] of [5] 

Diesel Fire Pump Engine Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

4.5 lb/hour 0.23 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 6.8 g/hp-hr

 Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

6.8 g/hp-hr x 300 hp x 1 lb/453.6 g = 4.5 lb/hr 

4.5 lb/hr x 100 hr x ton/2,000 lb = 0.23 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one engine.
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [2] of [5] 

Diesel Fire Pump Engine Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

6.8 g/hp-hr

4. Equivalent Allowable Emissions: 

4.5 lb/hour 0.23 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [3] of [5] 

Diesel Fire Pump Engine Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.0036 lb/hour 0.00018 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.0015% S fuel oil

 Reference: FPL, 2011

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.0015% S x 64/32 (MW SO2/S) x 7.06 lb/gal x 16.9 gal/hr = 0.0036 lb/hr 

0.0036 lb/hr x 100 hr x ton/2,000 lb = 0.00018 TPY

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one engine.
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [3] of [5] 

Diesel Fire Pump Engine Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.0015% S fuel oil

4. Equivalent Allowable Emissions: 

0.0036 lb/hour 0.00018 tons/year 

5. Method of Compliance: 

Fuel vendor information

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [4] of [5] 

Diesel Fire Pump Engine Particulate Matter - PM/PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM/PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.26 lb/hour 0.013 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 0.4 g/hp-hr

 Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

0.4 g/hp-hr x 300 hp x 1 lb/453.6 g = 0.26 lb/hr 

 0.26 lb/hr x 100 hr/2,000 lb = 0.013 TPY 

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one engine.
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [4] of [5] 

Diesel Fire Pump Engine Particulate Matter - PM/PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.4 g/hp-hr

4. Equivalent Allowable Emissions: 

0.26 lb/hour 0.013 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII Standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 29 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [5] of [5] 

Diesel Fire Pump Engine Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.66 lb/hour 0.033 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 1.0 g/hp-hr

 Reference: Manufacturer certification

7. Emissions 

 Method Code: 

2

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

1.0 g/hp-hr x 300 hp x 1 lb/453.6 g = 0.66 lb/hr 

 0.66 lb/hr x 100 hr/2,000 lb = 0.033 TPY 

11. Potential, Fugitive, and Actual Emissions Comment: 

Emissions are for one engine.
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [6] Page [5] of [5] 

Diesel Fire Pump Engine Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

RULE

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

1.0 g/hp-hr

4. Equivalent Allowable Emissions: 

0.66 lb/hour 0.033 tons/year 

5. Method of Compliance: 

Manufacturer certification of Subpart IIII Standards.

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 1

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C. requires 20 percent opacity. Excess emissions 

provided by Rule 62-210.700.

Visible Emissions Limitation: Visible Emissions Limitation of 

1. Visible Emissions Subtype: 

 

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: 

5. Visible Emissions Comment: 
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [6] 

Diesel Fire Pump Engine

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
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Effective: 03/11/2010 14 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers 

III. EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Application - For Title V air operation permitting only, emissions units 

are classified as regulated, unregulated, or insignificant. If this is an application for an initial, revised or 

renewal Title V air operation permit, a separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each regulated and unregulated emissions unit 

addressed in this application. Some of the subsections comprising the Emissions Unit Information 

Section of the form are optional for unregulated emissions units. Each such subsection is appropriately 

marked. Insignificant emissions units are required to be listed at Section II, Subsection C. 

Air Construction Permit or FESOP Application - For air construction permitting or federally 

enforceable state air operation permitting, emissions units are classified as either subject to air permitting 

or exempt from air permitting. The concept of an “unregulated emissions unit” does not apply. If this is 

an application for an air construction permit or FESOP, a separate Emissions Unit Information Section 

(including subsections A through I as required) must be completed for each emissions unit subject to air 

permitting addressed in this application for air permit. Emissions units exempt from air permitting are 

required to be listed at Section II, Subsection C. 

Air Construction Permit and Revised/Renewal Title V Air Operation Permit Application – Where 

this application is used to apply for both an air construction permit and a revised or renewal Title V air 

operation permit, each emissions unit is classified as either subject to air permitting or exempt from air 

permitting for air construction permitting purposes, and as regulated, unregulated, or insignificant for 

Title V air operation permitting purposes. A separate Emissions Unit Information Section (including 

subsections A through I as required) must be completed for each emissions unit addressed in this 

application that is subject to air construction permitting and for each such emissions unit that is a 

regulated or unregulated unit for purposes of Title V permitting. (An emissions unit may be exempt from 

air construction permitting but still be classified as an unregulated unit for Title V purposes.) Emissions 

units classified as insignificant for Title V purposes are required to be listed at Section II, Subsection C. 

If submitting the application form in hard copy, the number of this Emissions Unit Information Section 

and the total number of Emissions Unit Information Sections submitted as part of this application must be 

indicated in the space provided at the top of each page. 
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EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

A. GENERAL EMISSIONS UNIT INFORMATION 

Title V Air Operation Permit Emissions Unit Classification 

1. Regulated or Unregulated Emissions Unit? (Check one, if applying for an initial, revised 

or renewal Title V air operation permit. Skip this item if applying for an air construction 

permit or FESOP only.) 

 The emissions unit addressed in this Emissions Unit Information Section is a regulated 

emissions unit. 

 The emissions unit addressed in this Emissions Unit Information Section is an 

unregulated emissions unit. 

Emissions Unit Description and Status

1. Type of Emissions Unit Addressed in this Section: (Check one) 

 This Emissions Unit Information Section addresses, as a single emissions unit, a 

single process or production unit, or activity, which produces one or more air 

pollutants and which has at least one definable emission point (stack or vent). 

 This Emissions Unit Information Section addresses, as a single emissions unit, a group 

of process or production units and activities which has at least one definable emission 

point (stack or vent) but may also produce fugitive emissions. 

 This Emissions Unit Information Section addresses, as a single emissions unit, one or 

more process or production units and activities which produce fugitive emissions only. 

2. Description of Emissions Unit Addressed in this Section: 

Temporary Construction Boilers (to be used during construction period only).

3. Emissions Unit Identification Number: 7

4. Emissions Unit 

 Status Code: 

 C

5. Commence 

 Construction 

 Date: 

 

6. Initial Startup 

 Date: 

 2015 

7. Emissions Unit 

 Major Group 

 SIC Code: 

 49 

8. Federal Program Applicability: (Check all that apply) 

 Acid Rain Unit 

 CAIR Unit 

9. Package Unit: 

 Manufacturer: Nebraska Boiler or equivalent Model Number: 

10. Generator Nameplate Rating: MW 

11. Emissions Unit Comment: 

These temporary emission units will only be used during the project construction 

period. Once the PEEC commences commercial operation, these units will no longer 

be operated.
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Effective: 03/11/2010 16 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers 

Emissions Unit Control Equipment/Method: Control 1 of 1

1. Control Equipment/Method Description: 

Low NOX burners

2. Control Device or Method Code: 205

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 

Emissions Unit Control Equipment/Method: Control of 

1. Control Equipment/Method Description: 

 

2. Control Device or Method Code: 
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Effective: 03/11/2010 17 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

3. Maximum Heat Input Rate: 150 million Btu/hr (up to)

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 1,500 hours/year 

6. Operating Capacity/Schedule Comment: 

These temporary emission units will only be used during the project construction 

period. Once the PEEC commences commercial operation, these units will no longer be 

operated.
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Effective: 03/11/2010 18 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

C. EMISSION POINT (STACK/VENT) INFORMATION 

(Optional for unregulated emissions units.) 

Emission Point Description and Type

1. Identification of Point on Plot Plan or 

 Flow Diagram: 

2. Emission Point Type Code: 

 

3. Descriptions of Emission Points Comprising this Emissions Unit for VE Tracking: 

 

4. ID Numbers or Descriptions of Emission Units with this Emission Point in Common: 

 

5. Discharge Type Code: 

 

6. Stack Height: 

 feet 

7. Exit Diameter: 

 Feet 

8. Exit Temperature: 

 F 

9. Actual Volumetric Flow Rate: 

 acfm 

10. Water Vapor: 

 % 

11. Maximum Dry Standard Flow Rate: 

 dscfm 

12. Nonstack Emission Point Height: 

 Feet 

13. Emission Point UTM Coordinates... 

 Zone: East (km): 

 North (km): 

14. Emission Point Latitude/Longitude... 

Latitude (DD/MM/SS) 

 Longitude (DD/MM/SS) 

15. Emission Point Comment: 

 Stack parameter may vary based on availability from vendors.
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Effective: 03/11/2010 19 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 2

1. Segment Description (Process/Fuel Type): 

Natural gas

2. Source Classification Code (SCC): 

 

3. SCC Units: 

MMscf

4. Maximum Hourly Rate: 

0.147

5. Maximum Annual Rate: 

220.6

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

2 grains/100 scf

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

1,020

10. Segment Comment: 

Maximum hourly and annual rates for each boiler. 

Maximum annual rate based on 1,500 hr/yr operation. 

Segment Description and Rate: Segment 2 of 2

1. Segment Description (Process/Fuel Type): 

Ultra low sulfur 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

1,000 gallons

4. Maximum Hourly Rate: 

1.110

5. Maximum Annual Rate: 

1,665.4

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

0.0015

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 

Maximum hourly and annual rates for each boiler. 

 Maximum annual rate based on 1,500 hr/yr operation. 
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Effective: 03/11/2010 20 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

E. EMISSIONS UNIT POLLUTANTS 

List of Pollutants Emitted by Emissions Unit

1. Pollutant Emitted 2. Primary Control 

 Device Code 

3. Secondary Control 

 Device Code 

4. Pollutant 

 Regulatory Code

PM Fuel Quality NS

PM10 Fuel Quality NS

SO2 Fuel Quality EL

NOX 205 EL

CO Good Combustion NS

VOC Good Combustion NS

 

 

 

 

 

 

 

 

 

 

 
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Effective: 03/11/2010 21 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [1] of [6] 

Temporary Construction Boilers Particulate Matter Total - PM

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter Total - PM

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

1.12 lb/hour 2.7 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

See Attachment F1 for calculations.

11. Potential, Fugitive, and Actual Emissions Comment: 

For each boiler.
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EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [1] of [6] 

Temporary Construction Boilers Particulate Matter Total - PM

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% Opacity

4. Equivalent Allowable Emissions: 

1.12 lb/hour 2.7 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 23 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [2] of [6] 

Temporary Construction Boilers Particulate Matter - PM10

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Particulate Matter - PM10

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

1.12 lb/hour 2.7 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 See Attachment F1 for calculations.

11. Potential, Fugitive, and Actual Emissions Comment: 

For each boiler.
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Effective: 03/11/2010 24 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [2] of [6] 

Temporary Construction Boilers Particulate Matter - PM10

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

10% Opacity

4. Equivalent Allowable Emissions: 

1.12 lb/hour 2.7 tons/year 

5. Method of Compliance: 

EPA Method 9

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 25 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [3] of [6] 

Temporary Construction Boilers Sulfur Dioxide - SO2

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Sulfur Dioxide - SO2

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.84 lb/hour 0.6 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 See Attachment F1 for calculations. 

11. Potential, Fugitive, and Actual Emissions Comment: 

For each boiler.
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Effective: 03/11/2010 26 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [3] of [6] 

Temporary Construction Boilers Sulfur Dioxide - SO2

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

2 grains S/100 scf gas

4. Equivalent Allowable Emissions: 

0.84 lb/hour 0.6 tons/year 

5. Method of Compliance: 

Fuel Sampling and Analysis

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 27 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [4] of [6] 

Temporary Construction Boilers Nitrogen Oxides - NOX

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Nitrogen Oxides - NOX

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

20.59 lb/hour 15.4 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 For each boiler.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
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Effective: 03/11/2010 28 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [4] of [6] 

Temporary Construction Boilers Nitrogen Oxides - NOX

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

0.050 lb/MMBtu

4. Equivalent Allowable Emissions: 

20.59 lb/hour 15.4 tons/year 

5. Method of Compliance: 

EPA Method 7e or Vendor Certification

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [5] of [6] 

Temporary Construction Boilers Carbon Monoxide - CO

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Carbon Monoxide - CO

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

12.35 lb/hour 9.3 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

3

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 See Attachment F1

11. Potential, Fugitive, and Actual Emissions Comment: 

For each boiler.
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Effective: 03/11/2010 30 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [5] of [6] 

Temporary Construction Boilers Carbon Monoxide - CO

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

12.35 lb/hour 9.3 tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 31 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [6] of [6] 

Temporary Construction Boilers Volatile Organic Compounds - VOC

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

Complete a Subsection F1 for each pollutant identified in Subsection E if applying for an 

air construction permit or concurrent processing of an air construction permit and a 

revised or renewal Title V operation permit. Complete for each emissions-limited pollutant 

identified in Subsection E if applying for an air operation permit. 

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

Volatile Organic Compounds - VOC

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

0.81 lb/hour 0.6 tons/year 

4. Synthetically Limited? 

 Yes No 

5. Range of Estimated Fugitive Emissions (as applicable): 

 to tons/year 

6. Emission Factor: 

Reference: Emissions based on AP-42

7. Emissions 

 Method Code: 

 

8.a. Baseline Actual Emissions (if required): 

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

9.a. Projected Actual Emissions (if required): 

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 See Attachment F1.

11. Potential, Fugitive, and Actual Emissions Comment: 

For each boiler.
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Effective: 03/11/2010 32 01/2012 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [7] Page [6] of [6] 

Temporary Construction Boilers Volatile Organic Compounds - VOC

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

Complete Subsection F2 if the pollutant identified in Subsection F1 is or would be subject 

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions 1 of 1

1. Basis for Allowable Emissions Code: 

OTHER

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

0.81 lb/hour 0.6 tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

6. Allowable Emissions Comment (Description of Operating Method): 

 
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Effective: 03/11/2010 33 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

G. VISIBLE EMISSIONS INFORMATION 

Complete Subsection G if this emissions unit is or would be subject to a unit-specific visible 

emissions limitation. 

Visible Emissions Limitation: Visible Emissions Limitation 1 of 2

1. Visible Emissions Subtype: 

VE20

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 20 % Exceptional Conditions: 100 % 

 Maximum Period of Excess Opacity Allowed: 60 min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

FDEP Rule 62-296.320(4)(b)1, F.A.C., requires 20% opacity. Excess emissions provided 

by Rule 62-210.700(1), F.A.C.

Visible Emissions Limitation: Visible Emissions Limitation 2 of 2

1. Visible Emissions Subtype: 

VE10

2. Basis for Allowable Opacity: 

 Rule Other

3. Allowable Opacity: 

 Normal Conditions: 10 % Exceptional Conditions: % 

 Maximum Period of Excess Opacity Allowed: min/hour 

4. Method of Compliance: EPA Method 9

5. Visible Emissions Comment: 

Proposed as emission limit for PM/PM10.
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Effective: 03/11/2010 34 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

H. CONTINUOUS MONITOR INFORMATION 

Complete Subsection H if this emissions unit is or would be subject to continuous 

monitoring. 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 

Continuous Monitoring System: Continuous Monitor of 

1. Parameter Code: 

 

2. Pollutant(s): 

 

3. CMS Requirement: Rule Other 

4. Monitor Information... 

Manufacturer: 

Model Number: Serial Number: 

5. Installation Date: 

 

6. Performance Specification Test Date: 

 

7. Continuous Monitor Comment: 

 
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Effective: 03/11/2010 35 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

I. EMISSIONS UNIT ADDITIONAL INFORMATION 

Additional Requirements for All Applications, Except as Otherwise Stated

1. Process Flow Diagram: (Required for all permit applications, except Title V air operation permit 

revision applications if this information was submitted to the department within the previous five 

years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

2. Fuel Analysis or Specification: (Required for all permit applications, except Title V air operation 

permit revision applications if this information was submitted to the department within the previous 

five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

3. Detailed Description of Control Equipment: (Required for all permit applications, except Title V 

air operation permit revision applications if this information was submitted to the department within 

the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: See Air Report Previously Submitted, Date 

4. Procedures for Startup and Shutdown: (Required for all operation permit applications, except 

Title V air operation permit revision applications if this information was submitted to the department 

within the previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable (construction application) 

5. Operation and Maintenance Plan: (Required for all permit applications, except Title V air 

operation permit revision applications if this information was submitted to the department within the 

previous five years and would not be altered as a result of the revision being sought)

 Attached, Document ID: Previously Submitted, Date 

 Not Applicable 

6. Compliance Demonstration Reports/Records: 

 Attached, Document ID: 

Test Date(s)/Pollutant(s) Tested: 

 

 Previously Submitted, Date: 

Test Date(s)/Pollutant(s) Tested: 

 

 To be Submitted, Date (if known): 

Test Date(s)/Pollutant(s) Tested: 

 

 Not Applicable 

Note: For FESOP applications, all required compliance demonstration records/reports must be 

submitted at the time of application. For Title V air operation permit applications, all required 

compliance demonstration reports/records must be submitted at the time of application, or a 

compliance plan must be submitted at the time of application. 

7. Other Information Required by Rule or Statute: 

 Attached, Document ID: See Air Report Not Applicable 
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Effective: 03/11/2010 36 01/2012 

EMISSIONS UNIT INFORMATION 

Section [7] 

Temporary Construction Boilers

I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) 

Additional Requirements for Air Construction Permit Applications

1. Control Technology Review and Analysis (Rules 62-212.400(10) and 62-212.500(7), 

F.A.C.; 40 CFR 63.43(d) and (e)): 

 Attached, Document ID: See Air Report Not Applicable 

2. Good Engineering Practice Stack Height Analysis (Rules 62-212.400(4)(d) and 62-

212.500(4)(f), F.A.C.): 

 Attached, Document ID: See Air Report Not Applicable 

3. Description of Stack Sampling Facilities: (Required for proposed new stack sampling facilities 

only) 

 Attached, Document ID: See Air Report Not Applicable 

Additional Requirements for Title V Air Operation Permit Applications

1. Identification of Applicable Requirements: 

 Attached, Document ID: 

2. Compliance Assurance Monitoring: 

 Attached, Document ID: Not Applicable 

3. Alternative Methods of Operation: 

 Attached, Document ID: Not Applicable 

4. Alternative Modes of Operation (Emissions Trading): 

 Attached, Document ID: Not Applicable 

Additional Requirements Comment

 
January 2012 

Maximum Heat Hourly Annual Annual

No. of Input Rate/Unit Fuel Usage a Operating Hours Fuel Usage a 

Pollutant Units (MMBtu/hr) (106 scf/hr) (hrs/yr) (106 scf/hr) 

(103gal/hr) (103gal/hr)

Natural Gas Combustion

PM/PM10 1 150.0 0.147 1,500 220.6 7.6 

SO2 1 150.0 0.147 1,500 220.6 2 

NOx 1 150.0 0.147 1,500 220.6 140.0 

CO 1 150.0 0.147 1,500 220.6 84 VOC d 1 150.0 0.147 1,500 220.6 5.5 Ultra Low-Sulfur Diesel Combustion

PM/PM10 1 150.0 1.110 1,500 1665.4 3.3 

SO2 1 150.0 1.110 1,500 1665.4 157 

NOx 1 150.0 1.110 1,500 1665.4 10.0 

CO 1 150.0 1.110 1,500 1665.4 5.0 VOC d 1 150.0 1.110 1,500 1665.4 0.2 Footnotes:

a Based on natural gas heat content of 1,020 Btu/scf and ultra low-sulfur distillate heat content of 131,500 Btu/gal, respectively.b Propane combustion emission factors are based on Tables 1.4-1 and 1.4-2, AP-42, Section 1.4, July 1998. Ultra low sulfur distillate 

 Tables 1.3-1, 1.3-2, and 1.3-3, AP-42, Section 1.3, September, 1998.

c "S" is sulfur content in natural gas. A sulfur content of 2.0 gr/100 scf is used in the calculation; in AP.42, default sulfur content is 0.2 d Non-methane total organic compounds.e "S" is weight percent of sulfur in oil. A sulfur content of 0.0015% by weight used in the calculation.

Emis

ATTACHMENT F1

EMISSION CALCULATIONS FOR CONSTRUCTION BOILERS

Rev. 0
AIR CONSTRUCTION PERMIT APPLICATION REPORT 
AIR CONSTRUCTION 

PERMIT APPLICATION 

FOR THE 

FPL PORT EVERGLADES 

NEXT GENERATION CLEAN ENERGY CENTER 

BROWARD COUNTY, FLORIDA 

Prepared For: 

Florida Power & Light Company 

700 Universe Boulevard 

Juno Beach, Florida 33408 

Prepared By: 

Golder Associates Inc. 

6026 NW 1st Place 

Gainesville, Florida 32607 

January 2012 

113-87618 
January 2012 - i - 113-87618 

TABLE OF CONTENTS 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

SECTION PAGE

1.0 INTRODUCTION .................................................................................................................. 1-1

2.0 PROJECT DESCRIPTION .................................................................................................... 2-1

2.1 Facility Description ................................................................................................... 2-1

2.2 Proposed Combustion Turbines ................................................................................ 2-1

2.3 Proposed Source Emission Units and Stack Parameters ........................................... 2-2

2.4 Annual Emissions for PEEC Including Emission Reductions from the 

Existing Units 1 through 4 ......................................................................................... 2-5

2.5 Annual Emissions for GHGs ..................................................................................... 2-7

2.6 Layout, Structures, and Stack Sampling Facilities .................................................... 2-8

2.7 Excess Emissions ...................................................................................................... 2-8

2.8 Proposed Permitted Capacity and Emission Limits .................................................. 2-9

2.9 Construction Boilers ................................................................................................ 2-10

3.0 AIR QUALITY REVIEW REQUIREMENTS AND APPLICABILITY .............................. 3-1

3.1 National, State, and Local AAQS ............................................................................. 3-1

3.2 PSD Requirements .................................................................................................... 3-1

3.2.1 General Requirements .................................................................................. 3-1

3.2.2 Greenhouse Gases ........................................................................................ 3-2

3.2.3 Control Technology Review ........................................................................ 3-3

3.2.4 Source Impact Analysis ................................................................................ 3-4

3.2.5 Air Quality Monitoring Requirements ......................................................... 3-5

3.2.6 Source Information/GEP Stack Height ........................................................ 3-6

3.2.7 Additional Impact Analysis .......................................................................... 3-7

3.2.8 Air Quality Related Values .......................................................................... 3-7

3.3 Nonattainment Rules ................................................................................................. 3-8

3.4 Emission Standards ................................................................................................... 3-8

3.4.1 New Source Performance Standards ............................................................ 3-8

3.4.2 National Emission Standards for Hazardous Air Pollutants ......................... 3-9

3.4.3 Florida Rules .............................................................................................. 3-10

3.4.4 Florida Air Permitting Requirements ......................................................... 3-10

3.4.5 Local Air Regulations ................................................................................ 3-10

3.5 Source Applicability ................................................................................................ 3-11

3.5.1 Area Classification ..................................................................................... 3-11
January 2012 - ii - 113-87618 

TABLE OF CONTENTS 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

3.5.2 PSD Review ............................................................................................... 3-11

3.5.3 Local Air Regulations ................................................................................ 3-13

3.5.4 Other Clean Air Act Requirements ............................................................ 3-13

4.0 CONTROL TECHNOLOGY DESCRIPTION ...................................................................... 4-1

4.1 Applicability .............................................................................................................. 4-1

4.2 Overview of Control Technology and Applicable NSPS .......................................... 4-1

4.2.1 Nitrogen Oxides ........................................................................................... 4-2

4.2.2 Carbon Monoxide ......................................................................................... 4-3

4.2.3 Sulfur Oxides (SO2 and H2SO4 Mist) ........................................................... 4-4

4.2.4 Particulate Matter and Other Regulated Pollutants ...................................... 4-4

4.2.5 Volatile Organic Compound ........................................................................ 4-5

4.3 GHG Control Technology Review ............................................................................ 4-5

4.3.1 BACT Analysis for PEEC – 3-on-1 Combined Cycle Unit ......................... 4-7

4.3.2 BACT Analysis for PEEC – Auxiliary Boiler, Emergency 

Generators, Natural Gas Heater, Natural Gas Compressor Station and 

Diesel Fire Pump Engine ............................................................................ 4-17

5.0 AMBIENT MONITORING ANALYSIS .............................................................................. 5-1

6.0 AIR QUALITY IMPACT ANALYSIS .................................................................................. 6-1

6.1 Air Modeling Analysis Approach ............................................................................. 6-2

6.1.1 Air Modeling Scenarios ............................................................................... 6-2

6.1.2 General Modeling Approach ........................................................................ 6-2

6.1.3 Model Selection ............................................................................................ 6-3

6.1.4 Meteorological Data ..................................................................................... 6-4

6.1.5 Emission Inventory ...................................................................................... 6-4

6.1.6 Building Downwash Effects ......................................................................... 6-6

6.1.7 Receptor Locations ....................................................................................... 6-7

6.1.8 Background Concentrations ......................................................................... 6-7

6.2 Model Results ............................................................................................................ 6-8

6.2.1 Air Quality Impacts for the Existing Units 1 through 4 ............................... 6-8

6.2.2 Air Quality Impacts due to PEEC ................................................................ 6-9

6.2.3 Air Quality Impacts Predicted at the Everglades NP ................................. 6-11

6.3 Conclusions ............................................................................................................. 6-11
January 2012 - iii - 113-87618 

TABLE OF CONTENTS 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

(Cont’d) 

LIST OF TABLES

Table 2-1A Stack, Operating, and Emission Data for the Combustion Turbines/HRSGs - Natural 

Gas Combustion, MPS 501J CT 

Table 2-1B Stack, Operating and Emission Data for the Combustion Turbines/HRSGs - Natural 

Gas Combustion, Siemens H CT 

Table 2-2A Stack, Operating, and Emission Data for the Combustion Turbines/HRSGs - Ultra 

Low-Sulfur Light Oil Combustion, MPS 501J CT 

Table 2-2B Stack, Operating, and Emission Data for the Combustion Turbines/HRSGs - Ultra 

Low-Sulfur Light Oil Combustion, Siemens H CT 

Table 2-3A Summary of Maximum Potential Annual Emissions for the CTs/HRSGs, MPS 501J 

CTs 

Table 2-3B Summary of Maximum Potential Annual Emissions for the CTs/HRSGs, Siemens H 

CTs 

Table 2-4 Performance, Stack Parameters, and Emissions for the Auxiliary Boiler 

Table 2-5 Performance and Emission Data for the Emergency Generators 

Table 2-6 Performance, Stack Parameters, and Emissions for the Natural Gas Fuel Heater 

Table 2-7 Estimated Performance and Emission Data for Fire Pump Engine 

Table 2-8 Performance and Emission Data for the Natural Gas Compressors 

Table 2-9A Summary of Maximum Potential Annual Emissions for PEEC, MPS 501J CTs 

Table 2-9B Summary of Maximum Potential Annual Emissions for PEEC, Siemens H CTs 

Table 2-10 Summary of Maximum Potential Annual HAP Emissions for PEEC 

Table 3-1 National and State AAQS, Allowable PSD Increments, and Significant Impact Levels 

Table 3-2 PSD Significant Emission Rates and De Minimis Monitoring Concentrations 

Table 3-3 Maximum Emission Changes Due to PEEC, including Emission Reductions due to the 

Existing Units 1 through 4 at Port Everglades Plant, Compared to the PSD Significant 

Emission Rates 

Table 4-1 Proposed Emission Limits for CTs/HRSGs for PEEC 

Table 5-1 Summary of Maximum Measured SO2, NO2, PM10, PM2.5, O3, and CO Concentrations 

Representative of PEEC Project, 2008 through 2010 

Table 6-1 Summary of Predicted Pollutant Concentrations for the Existing Units 1 through 4 at 

Port Everglades Plant and PEEC Compared to Ambient Air Quality Standards 

Table 6-2 Major Features of the AERMOD Model, Version 11353 

Table 6-3 Existing FPL Port Everglades Plant, Units 1, 2, 3, and 4 – Stack, Operating and 

Emissions Data 

Table 6-4 Summary of Predicted Pollutant Concentrations for the Existing Units 1 through 4 at 

Port Everglades Plant Compared to Ambient Air Quality Standards 
January 2012 - iv - 113-87618 

TABLE OF CONTENTS 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

Table 6-5 Summary of Maximum Pollutant Concentrations Predicted for Natural Gas- and 

Distillate Fuel Oil-Firing for PEEC 

Table 6-6 Maximum Pollutant Concentrations Predicted for PEEC Compared to the AAQS 

Table 6-7 Summary of Pollutant Concentrations Predicted for the PEEC Auxiliary Boiler 

Compared to EPA Ambient Air Quality Standards 

Table 6-8 Maximum Pollutant Concentrations Predicted for PEEC and the Existing Units 1 

through 4 at Port Everglades Plant at the PSD Class I Area of the Everglades National 

Park 

LIST OF FIGURES

Figure 1-1 General Location of the FPL Port Everglades Plant and Port Everglades Energy Center 

Figure 2-1 Conceptual Plot Plan 

Figure 2-2 Process Flow Diagram for Each CT/HRSG Train Baseload Operation, Turbine Inlet 

Temperature of 75°F 

Figure 2-3 Comparison of Historical Actual SO2, NOx and PM10 Annual Emissions (TPY) for the 

Existing Units 1 through 4 at Port Everglades Plant Compared to Projected Maximum 

Potential Annual Emissions (TPY) for PEEC 

Figure 2-4 Comparison of CO2 Emission Rates (lb/MW-hr) for the Existing Units 1 through 4 at 

Port Everglades Plant and PEEC 

Figure 2-5 Profile of PEEC – North-South Elevations 

Figure 2-6 Profile of PEEC – East-West Elevations 

Figure 6-1 Maximum Total Air Quality Impacts of the Existing Units 1 through 4 at Port 

Everglades Plant and PEEC Compared to Ambient Air Quality Standards 

LIST OF APPENDICES

A Expected Performance and Emission Information for MPS “J” CTs 

B Expected Performance and Emission Information for Siemens “H” CTs 

C Historical Actual Emission from Existing Units 1 through 4 at the FPL Port Everglades Plant 

D Receptor Location Figures and Profile Input Program (BPIP) Files 

E Model Summary and Input Files 
January 2012 - v - 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

LIST OF ACRONYMS 

°C degrees Celsius 

°F degrees Fahrenheit 

μg/m3

micrograms per cubic meter

AAQS Ambient Air Quality Standards 

AERMOD American Meteorological Society and U.S. Environmental Protection Agency 

Regulatory Model 

AOR Annual Operating Report 

AQRV air quality related value 

BACT Best Available Control Technology 

BPIP Building Profile Impact Program 

Btu/lb British thermal unit per pound 

Btu/kWh British thermal unit per kilowatt hour 

Btu/scf British thermal unit per standard cubic foot 

CAA Clean Air Act 

CCEC Cape Canaveral Energy Center 

CEM continuous emissions monitoring 

cf/yr cubic foot per year 

CFR Code of Federal Regulations 

CH4 methane 

CO carbon monoxide 

CO2 carbon dioxide 

CO2e carbon dioxide equivalent 

CT combustion turbine 

DLE dry low emissions 

DLN dry low NOx

EPA U.S. Environmental Protection Agency 

F.A.C. Florida Administrative Code 

FDEP Florida Department of Environmental Protection 

FGT Florida Gas Transmission Company, LLC 

FIU Florida International University 

FPL Florida Power & Light 

ft foot 

FR Federal Register 

FFFSGU fossil fuel fired steam generating unit 

g/bhp-hr grams per brake horsepower-hour 

g/s grams per second 

GEP Good Engineering Practice 

gr/100 scf grains per 100 standard cubic feet 
January 2012 - vi - 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

GHG greenhouse gas 

HAP hazardous air pollutant 

HFCs hydrofluorocarbons 

HHV higher heating value 

hp horsepower 

hr/yr hours per year 

HRSG heat recovery steam generator 

HSH highest, second highest 

Hz hertz 

I Interstate highway 

ICW Intracoastal Waterway 

km kilometer 

kW kilowatt 

lb/hr pound per hour 

lb/MMBtu pound per million British thermal units 

lb/MW-hr pound per megawatt-hour 

LHV lower heating value 

m meter 

MACT Maximum Available Control Technology 

MMBtu/hr million British thermal units per hour 

MMcf/hr million cubic feet per hour 

MPS Mitsubishi Power Systems 

MW megawatt 

NAD83 North American Datum 83 

NESHAP National Emission Standards for Hazardous Air Pollutants 

NP National Park 

N2O nitrous oxide 

NO2 nitrogen dioxide 

NOx nitrogen oxides 

NP National Park 

NSPS New Source Performance Standards 

NSR New Source Review 

NWA National Wilderness Area 

NWS National Weather Service 

O2 oxygen 

PFCs perfluorocarbons 

PM particulate matter 

PM2.5 particulate matter less than 2.5 microns 

PM10 particulate matter less than 10 microns 
January 2012 - vii - 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

ppb parts per billion 

ppbvd parts per billion by volume dry 

ppm parts per million 

ppmvd parts per million by volume dry 

PSD Prevention of Significant Deterioration 

PEEC Port Everglades Next Generation Clean Energy Center 

psia pound per square inch absolute 

psig pound per square inch gauge 

QA/QC quality assurance/quality control 

RICE reciprocating internal combustion engines 

SAM sulfuric acid mist 

scf/yr standard cubic foot per year 

SCR selective catalytic reduction 

SCRAM Support Center for Regulatory Air Models 

SER significant emissions rate 

SF6 sulfur hexafluoride 

SO2 sulfur dioxide 

S.R. State Road 

ST steam turbine 

TPY tons per year 

TSP total suspended particulate 

TTN Technology Transfer Network 

ULSD ultra low sulfur distillate “light oil” 

USGS U.S. Geological Survey 

UTM Universal Transverse Mercator 

VOC volatile organic compound 

WCEC West County Energy Center 
January 2012 1-1 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

1.0 INTRODUCTION 

Florida Power & Light Company’s (FPL’s) existing Port Everglades Plant consists of two nominal 

200 megawatt (MW) fossil fuel-fired steam generating units (FFFSGU) (Units 1 and 2), two nominal 

400 MW FFFSGU (Units 3 and 4), and 12 simple cycle natural gas turbines (GT1 - GT12). Units 1 

and 2 began operation in 1960 and 1961, respectively. The commercial in service dates for Units 3 

and 4 were 1964 and 1965, respectively. All four units have remained in service since these dates. 

Units 1 through 4 are authorized to operate pursuant to Florida Department of Environmental 

Protection (FDEP) Final Title V Permit No. 0110036-009-AV on natural gas, No. 6 fuel oil, No. 2 

fuel oil, propane, and on-specification used oil from FPL operations. 

Units 1 and 2 have a permitted maximum heat input of 2,300 million British thermal units per hour 

(MMBtu/hr) on oil and 2,400 MMBtu/hr on natural gas. Units 3 and 4 have a permitted maximum 

heat input of 4,000 MMBtu/hr on oil and 4,180 MMBtu/hr on natural gas. The air emissions from 

each unit are exhausted through four separate approximately 340 foot (ft) stacks. The 12 simple cycle 

natural gas turbines have a nominal capacity of 500 MW with a heat input of 8,424 MMBtu/hr and 

are capable of firing natural gas and/or No. 2 fuel oil. The general location of the existing Plant is 

shown in Figure 1-1. 

FPL proposes to modernize the existing Port Everglades Plant Units 1 through 4 into a highly 

efficient, lower emission next generation clean energy center using the latest combined cycle 

technology (the Project). This Air Construction Permit Application/Greenhouse Gas (GHG) 

Prevention of Significant Deterioration (PSD) Application consists of the retirement and replacement 

of the existing Units 1 through 4 with one nominal 1,250 MW “3-on-1” combined cycle unit. The “3-

on-1” unit will consist of three nominal 250 MW advanced combustion turbines (CTs) and three heat 

recovery steam generators (HRSGs), which will utilize the waste heat from the CTs to produce steam 

to be utilized in a single nominal 500 MW steam turbine generator. The “3-on-1” unit is referred to 

as the Port Everglades Next Generation Clean Energy Center (PEEC). The 12 existing natural gas 

turbines are not a part of PEEC. PEEC will be located within the existing FPL property boundaries. 

Dismantlement of the existing generation units will be required prior to the construction of PEEC. 

Therefore, there will be no overlap of operation between the existing units and PEEC, which is 

anticipated to commence commercial operation in June 2016. 
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There will be significant benefits associated with PEEC. The Project will result in increased power 

generation without using additional land and water sources. PEEC will be more energy efficient than 

the existing units and will provide cleaner energy to FPL’s customers. PEEC will use approximately 

35 percent less fuel than the existing units, for an equivalent amount of electricity production. 

In addition, regulated air emissions with the Project will be approximately 90 percent lower than the 

existing emissions for Units 1 through 4, resulting in significant air quality benefits. There will also 

be significant reductions in FPL’s system wide carbon dioxide (CO2) emissions from 2016 through 

2047 with the Project. CO2 emissions on a system wide basis will be lower with PEEC – a 

cumulative reduction of approximately 22 million tons of CO2 emissions from 2016 through 2047 as 

a direct result of the Project. 

PEEC will improve air quality not only in the vicinity of the facility but also in areas further away 

from the facility, such as the Everglades National Park (NP). The maximum total air quality impacts 

for PEEC are predicted to be well below and in compliance with the AAQS. For pollutants such as 

sulfur dioxide (SO2) and nitrogen dioxide (NO2), PEEC’s total air quality impacts are predicted to be 

approximately 40 percent or more lower than those predicted for Units 1 through 4. 

The CTs being evaluated for PEEC include the Mitsubishi Power Systems (MPS) “J” CTs and 

Siemens Power Generation, Inc. (Siemens) “H” CTs, or their equivalents. The information presented 

in this application envelopes the performance and emissions for both types of CTs. 

Each CT will utilize inlet air cooling and may consist of evaporative cooling or an alternative system. 

Evaporative cooling systems achieve adiabatic cooling using water in the form of water evaporated 

from a treated paper material. The evaporated water extracts the latent heat of vaporization from the 

inlet air stream when the water droplet is converted to water vapor. Heat is removed at a rate of 1,075 

British thermal units per pound (Btu/lb) of water. The result is a cooler, denser air stream. This 

allows additional power to be produced. The CTs will use natural gas as the primary fuel with ultra 

low sulfur distillate (ULSD) “light oil” used as a backup fuel for up to the equivalent of 1,000 hours 

per year (hr/yr) per CT at baseload conditions. 

Natural gas for PEEC will be transported to the facility via pipeline. No onsite storage will be 

provided for natural gas. Natural gas compressors will be installed to raise the natural gas pressure to 
January 2012 1-3 113-87618 

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the appropriate level for the CTs. ULSD oil will be delivered to the facility by truck or pipeline and 

will be stored in a new fuel oil storage tank. 

The U.S. Environmental Protection Agency’s (EPA’s) PSD regulations are promulgated under 

Title 40, Part 51.166 of the Code of Federal Regulations (40 CFR 51.166). Florida’s PSD regulations 

are codified in FDEP Rule 62-212.400, Florida Administrative Code (F.A.C.) and have been 

approved by EPA. The Florida PSD regulations incorporate the requirements of EPA’s PSD 

regulations. Under these requirements, the existing Port Everglades Plant is classified as an existing 

major facility. A modification to an existing major facility that results in a significant net emissions 

increase equal to or exceeding the significant emissions rates (SERs) listed in the Florida regulations 

under Section 62-212.400, Table 62-212.400-2, F.A.C., is classified as a major modification and will 

be subject to the PSD preconstruction permitting program for those pollutants that exceed the PSD 

SERs. 

The procedures for determining applicability of the PSD permitting program to PEEC are specified in 

FDEP Rule 62-212.400(2), F.A.C. For each regulated pollutant, PSD is triggered as a result of a 

modification at an existing facility if the difference between the projected actual emissions and the 

baseline actual emissions equals or exceeds the SER for that pollutant, as defined at FDEP 

Rule 62-210.200 (243), F.A.C. 

On June 3, 2010, EPA promulgated regulations related to PSD and Title V GHG Tailoring Rule 

[75 Federal Register (FR) 31514-31608]. This change in EPA’s PSD regulations requires PSD 

review and approval for new major projects and modifications exceeding the PSD thresholds for 

review. This application includes information to address PSD review of GHGs under EPA’s rules. 

Florida has deferred review and approval of projects undergoing PSD review for GHGs to EPA 

Region IV. 

There will be significant reductions in regulated air emissions for PEEC except for GHGs. The net 

changes in air emissions, as presented in Section 2.0, will not exceed the PSD SERs for any of the 

criteria pollutants subject to PSD review, except for GHGs. Therefore, pursuant to FDEP Rule 62-

212.400, F.A.C., PSD review is applicable for GHG by EPA but not for any of the other regulated air 

pollutants for the Project. 
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This Air Construction Permit Application Report is divided into six major sections. This Application 

is being filed for the purpose of establishing federally enforceable emission limitations that ensure the 

Project will not result in a significant net increase in emissions of any regulated air pollutant, in 

accordance with FDEP’s federally approved major source air construction permit program under 

Florida's federally required State Implementation Plan: 

 Section 2.0 presents a description of PEEC, including air emissions and stack 

parameters. 

 Section 3.0 provides a review of the regulatory analysis conducted, including 

PSD and nonattainment requirements, applicable to PEEC. 

 Section 4.0 includes the control technology review including a Best 

Available Control Technology (BACT) analysis for GHG. 

 Section 5.0 discusses the ambient air monitoring analysis. 

 Section 6.0 presents a summary of the air modeling approach and results 

used in assessing compliance of the existing Units 1 through 4 and PEEC 

with ambient air quality standards (AAQS). 
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2.0 PROJECT DESCRIPTION 

2.1 Facility Description 

The existing FPL Port Everglades Plant is located within the City of Hollywood, in Broward County, 

Florida. The existing plant is situated within approximately 92.5 acres of land owned by FPL. The 

FPL owned property is also in the midport section within the jurisdictional area of Port Everglades. 

The facility is surrounded by other Port Everglades facilities and associated industrial activities, such 

as oil storage, cruise ship docking, and light commercial use. The facility has convenient access to 

State Road (S.R.) 84 and Interstate (I)-595 and is locally accessible by Eller Drive to the south. 

Roadways that surround the facility include SE 14th Avenue to the east, Eisenhower Drive to the west, 

and SE 26th Street to the north. The Port entrance channel and the Intracoastal Waterway (ICW) are 

approximately 0.5 mile to the east of the FPL property. 

Figure 2-1 presents the plot plan for PEEC. 

2.2 Proposed Combustion Turbines 

PEEC will be configured as a 3-on-1 combined cycle unit. The CTs (any of the models under 

consideration or equivalent) will use dry low-NOx (DLN) combustion technology when firing natural 

gas and water injection when firing ULSD oil to minimize formation of nitrogen oxides (NOx). 

Selective catalytic reduction (SCR) will be installed in each HRSG to further reduce emissions of 

NOx. Natural gas will be used as the primary fuel and ULSD oil will be used as a backup fuel. Light 

oil usage will be based on the equivalent of 1,000 hr/yr per CT at full load. 

The generating capacity of a combined cycle plant is affected by ambient temperature, with increased 

temperature resulting in less efficient electric production. Greater overall fuel consumption will 

occur at lower ambient temperatures. For the purpose of calculating maximum hourly fuel use 

quantities representative of a nominal 1,250 MW combined cycle unit, the following specific 

operating conditions were used for the CTs (see Appendices A and B): 

 35 degrees Fahrenheit (°F) dry bulb turbine inlet temperature, 

 60 percent relative humidity, 

 Approximately 20,940 Btu/lb and 920 British thermal units per standard 

cubic foot (Btu/scf), lower heating value (LHV), of natural gas 

[approximately 23,300 Btu/lb and 1,020 Btu/scf, higher heating value 

(HHV)], and 
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 Approximately 18,400 Btu/lb and 129,900 Btu/ gallon, LHV, for ULSD oil 

(approximately 19,500 Btu/lb and 137,700 Btu/gallon, HHV). 

The maximum heat input for the CTs being considered for PEEC ranges from 2,733 MMBtu/hr, LHV 

(3,034 MMBtu/hr, HHV), to 2,503 MMBtu/hr, LHV (2,774 MMBtu/hr, HHV), when firing natural 

gas (100 percent capacity, 35°F). The corresponding maximum fuel usage ranges from about 3.0 

million cubic feet per hour (MMcf/hr) to 2.7 MMcf/hr of natural gas for each CT. Maximum 

potential fuel usage at 75°F turbine inlet temperature ranges from about 6.6 × 1010 cubic feet per year 

(cf/yr) to 7.3 × 1010 cf/yr of natural gas for PEEC. 

ULSD oil use will be based on the equivalent of 1,000 hr/yr per CT at full load. The maximum fuel 

use is about 19,400 gallons per hour per CT at 35°F turbine inlet with a maximum annual usage rate 

of 58 million gallons for three CTs each operating for 1,000 hours. 

2.3 Proposed Source Emission Units and Stack Parameters 

PEEC’s air emission units are: 

 3 CT/HRSGs, 

 Auxiliary boiler (for the MPS “J” CTs for startup), 

 Fuel heater, 

 Emergency generators, 

 Fire pump engine, 

 Fuel oil storage tank, and 

 Compressor station. 

Each of these emission units is discussed in the following paragraphs. 

Performance, estimated maximum hourly emissions, and exhaust information representative of each 

CT/HRSG option operating at baseload conditions (100 percent load) in combined cycle mode are 

presented in Tables 2-1 and 2-2 for natural gas and light oil firing, respectively. Tables 2-1 and 2-2 

are presented as versions “A” and “B”, which are representative of the MPS “J” and Siemens “H” CT 

models, respectively. The data are presented for a turbine inlet temperature of 75F. The 

performance and emissions data for the other operating conditions are given in Appendices A and B 

for turbine inlet temperatures of 35F, 59F, 75°F, and 95F and various operating load conditions. 
January 2012 2-3 113-87618 

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Maximum potential annual emissions for the CTs/HRSGs for regulated air pollutants are based on an 

ambient temperature of 75°F. This turbine inlet temperature is conservative, since the annual average 

temperature is slightly higher than 75°F. To produce the maximum annual emissions, it is assumed 

that each CT/HRSG would operate for 8,760 hours. Of the 8,760 operating hours, an average of 

7,760 hr/yr are assumed to be natural gas firing. For the remaining average of 1,000 hr/yr, the CTs 

are assumed to operate on light oil. 

Since the ULSD (0.0015 percent) oil has lower fuel sulfur content than that assumed for natural gas 

(2 gr/100 scf), the maximum annual SO2 and sulfuric acid mist (SAM) emissions are based on 8,760 

hours of operation firing natural gas. Tables 2-3A and 2-3B present the maximum potential annual 

emissions for the range of operating conditions for each CT being considered for PEEC. 

A process flow diagram of the proposed CT/HRSG configuration, operating at baseload conditions 

with a compressor inlet temperature of 75°F, is presented in Figure 2-2. 

During combustion, two primary types of NOx are formed: fuel NOx and thermal NOx. Fuel NOx

emissions are formed through the oxidation of a portion of the nitrogen contained in the fuel. 

Thermal NOx emissions are generated through the oxidation of a portion of the nitrogen contained in 

the combustion air. NOx formation can be limited by lowering combustion temperatures (through 

water or steam injection) and/or staging combustion (a reducing atmosphere followed by an oxidizing 

atmosphere, known as DLN control). Emissions of NOx for the CTs, equipped with SCR control 

systems are proposed at concentrations of 2 parts per million by volume dry (ppmvd) conditions, 

corrected to 15 percent oxygen (O2) or less when firing natural gas and 8 ppmvd corrected to 

15 percent O2 or less when firing ULSD oil. 

Carbon monoxide (CO) is formed by incomplete combustion of fuel. High combustion temperatures, 

adequate excess air, and good fuel/air mixing during combustion will minimize CO formation. CO 

formation is limited by ensuring complete efficient combustion of the fuel in the turbines. Recent 

improvements in CT combustor technology allow for both reduced NOx emissions and low CO 

emissions. 

The expected CO stack emission rates for the MPS “J” CTs or equivalent when firing natural gas are 

9 ppmvd corrected to 15 percent O2 at baseload operation and 35 ppmvd corrected to 15 percent O2

with ULSD oil firing. For the Siemens “H” CTs, the expected CO emission rates when firing natural 
January 2012 2-4 113-87618 

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gas are 5 ppmvd corrected to 15 percent O2 at baseload operation, and 10 ppmvd corrected to 15 

percent O2 with ULSD oil firing. 

Similarly, volatile organic compound (VOC) emissions are formed by incomplete combustion of fuel. 

High combustion temperatures, adequate excess air, and good fuel/air mixing during combustion will 

minimize VOC formation. VOC formation is limited by ensuring complete efficient combustion of 

the fuel in the CTs. Recent improvements in CT combustor technology allow for both reduced NOx

emissions and low VOC emissions. 

The expected VOC emission rates for the MPS “J” CTs or equivalent at baseload operation when 

firing natural gas are 1.0 ppmvd corrected to 15 percent O2 at baseload operation and 10 ppmvd 

corrected to 15 percent O2 for ULSD oil firing. For the Siemens “H” CTs or equivalent at baseload 

operation, the expected VOC emission rates when firing natural gas are 1.0 ppmvd corrected to 15 

percent O2 at baseload operation and 10 ppmvd corrected to 15 percent O2 for ULSD oil firing. 

SO2 emission rates are controlled and minimized by the very low sulfur content in the fuels, which 

will be a maximum of 2 gr/100 scf sulfur for natural gas and 0.0015 percent sulfur by weight for 

ULSD oil. 

An auxiliary boiler will be used with the MPS “J” CTs, as necessary, for startup. The combustor 

requires steam for combustor cooling, which normally comes from the HRSG. The limited use 

auxiliary boiler will have a maximum heat input of 99.8 MMBtu/hr, HHV, firing natural gas. Table 

2-4 presents performance and emissions information for the auxiliary boiler. 

PEEC will be equipped with two 2,250 kilowatt (kW) emergency generators firing ULSD oil. These 

emergency generators will be used when electric power is not available. This primarily would occur 

during catastrophic events such as hurricanes. Table 2-5 contains emissions and manufacturer’s 

information for the emergency generators proposed for PEEC. Normally these emergency generators 

would be operated 1 to 2 hours per month for maintenance and reliability testing. 

PEEC may include one natural gas fired fuel heater. This heater will utilize a heat transfer fluid for 

heating the natural gas and be fired with only natural gas. This heater will have a maximum heat 

input rate of 9.9 MMBtu/hr (HHV) or less and will be used as necessary to heat natural gas above the 

dew point. Table 2-6 contains performance and emissions information for the fuel heater. 
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PEEC will be equipped with a 300 horsepower (hp) fire pump engine using ULSD oil. This engine 

will be used when necessary during catastrophic events such as fires. Table 2-7 presents emissions 

and manufacturer’s information for the fire pump engine proposed for PEEC. Normally, this fire 

pump engine would be operated only 1 to 2 hours per month for maintenance and reliability testing. 

PEEC may include a new natural gas compressor station to increase pressure from the existing 

Florida Gas Transmission Company, LLC (FGT) pipeline to the CTs. The natural gas compressor 

station, if installed onsite, would consist of three Solar Centaur 50 compressor sets or equivalent, with 

each set including a natural gas turbine and natural gas compressor. During normal operation, only 

two of the three compressor sets will operate at any given time. Table 2-8 presents performance and 

emissions information for the natural gas compressors. 

ULSD oil will be either trucked or barged to the facility and stored in a new fuel oil tank at the 

facility. This tank is a vertical fixed roof design, with a rated storage capacity of approximately 7 

million gallons (165,000 barrels). Appendix A provides performance and emissions information for 

the fuel oil storage tank. 

2.4 Annual Emissions for PEEC Including Emission Reductions from the Existing Units 1 

through 4 

The maximum annual potential emissions for PEEC include air emissions from the CT/HRSGs, fuel 

heater, emergency generators, auxiliary boiler, fire pump engine, fuel oil storage tank and natural gas 

compressor station. Tables 2-9A and 2-9B present the maximum annual potential PEEC emissions 

with the MPS “J” and Siemens “H” CTs, respectively. These tables address the criteria pollutants, as 

required, under new source review. 

In addition, maximum annual potential hazardous air pollutants (HAPs) emissions are presented in 

Table 2-10 for both CT models. Additional detail on the HAP emission calculations is also presented 

in Appendices A and B. The Port Everglades Plant will continue to be a major source of hazardous 

air pollutant (HAP) emissions due to the combined potential emissions from PEEC and the 12 gas 

turbines units exceed the major source for HAPs [10 tons per year (TPY) of a single HAP, or 25 TPY 

for all HAPs]. 

Annual emissions were based on maximum emissions for baseload operation and ambient 

temperatures of 75°F. The maximum emissions are based on 7,760 hr/yr firing natural gas and 
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1,000 hr/yr firing oil. The potential emissions are based on the 75°F turbine inlet temperature at 

100 percent load condition, since it represents the annual average temperature. 

Tables 2-9A and 2-9B compare the net emission changes due to the Project, reflecting the maximum 

PEEC emissions as well as the emission reductions from retirement of the existing Units 1 through 4 

at the Port Everglades Plant, to the PSD SERs. The PSD SERs are the emission thresholds to 

determine if PSD review will be required for modifications to major sources. The historical actual 

emissions for the existing Port Everglades Plant that are presented in these tables were determined 

pursuant to FDEP PSD Rules, specifically FDEP Rule 62-212.400 (2)(a)1., F.A.C. Five years (2006 

through 2010) of historical emission data were evaluated to determine historical actual emissions 

using the highest 2 year average emissions for each pollutant. Historical actual emissions are based 

on past Annual Operating Reports (AORs), which are presented in a series of tables in Appendix C 

for each unit for each year. In Tables 2-9A and 2-9B, the net emission changes (i.e., projected 

maximum potential emissions minus historical actual emissions) are compared to the PSD SERs. If 

the PSD SER for a pollutant is not exceeded by this comparison, PSD review is not required for that 

pollutant. 

This Application is being filed for the purpose of establishing federally enforceable emission 

limitations that ensure PEEC will not result in a significant net increase in emissions of any regulated 

air pollutant, except for GHG, in accordance with FDEP’s federally approved minor source air 

construction permit program under Florida's federally required State Implementation Plan. 

As shown in these tables, there are significant emission reductions for most pollutants. For SO2, 

particulate matter (PM), particulate matter less than 10 microns (PM10), and NOx, annual emissions 

will be reduced by more than 90 percent with PEEC. Although annual VOC emissions will increase 

slightly, the change will be less than the PSD SER. 

The net emission reductions for SO2, NOx, and PM10 as a result of the Project are also graphically 

depicted in Figures 2-3 and 2-4. Figure 2-3 provides a graphical comparison of historical actual 

annual TPY emissions from the existing Port Everglades Plant Units 1 through 4 with the projected 

maximum potential emissions resulting from PEEC. As shown in Figure 2-3, PEEC will result in 

reductions of SO2, NOx, and PM10 of 9,273 TPY (97.7% reduction), 3,878 TPY (91% reduction) and 

358 TPY (59% reduction), respectively. 
January 2012 2-7 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

Figure 2-4 compares the maximum potential emission rates for PEEC with historical actual GHG 

emission rates based on the amount of energy produced [i.e., a comparison on a pound per megawatt 

hour (lb/MW-hr) basis]. PEEC will result in over a 50 percent reduction in the rate of GHG 

emissions with a 943 lb/MW-hr reduction in GHG emissions. 

Based on this evaluation, the net emission changes for PEEC are less than the PSD SERs for all 

pollutants, except GHG. As such, PSD review by EPA is required for GHG but not the other 

regulated pollutants. Therefore, a BACT evaluation was performed for GHG. In addition, the air 

emission controls for the other regulated pollutants are presented to demonstrate that these controls 

are representative of BACT emission limits that have been determined under PSD regulations for 

other similar combined cycle units [e.g., PSD-FL-396, July 30, 2008, for West County Energy Center 

(WCEC) Unit 3]. 

2.5 Annual Emissions for GHGs 

On June 3, 2010, EPA promulgated regulations related to Prevention of Significant Deterioration and 

Title V Greenhouse Gas Tailoring Rule (75 FR 31514-31608). In EPA’s promulgation, GHGs are 

defined to include an aggregate group of six GHGs: CO2, methane (CH4), nitrous oxide (N2O), 

hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), and sulfur hexafluoride (SF6). Each of these 

GHGs has a specific Global Warming Potential that is calculated as “CO2 equivalent emissions” or 

CO2e that is equivalent to one ton of CO2. 

For PEEC, the GHGs emitted are CO2, CH4, and N2O with one ton of CH4 equivalent to 21 tons of 

CO2e and one ton of N2O equivalent to 310 tons of CO2e. Tables 2-9A to 2-9B present the net 

emission changes resulting from the Project, reflecting the maximum projected PEEC emissions and 

the resulting changes compared to the existing Units 1 through 4, and the PSD SERs, which are 

thresholds for PSD review for modifications to major sources. 

The CO2 emission rates shown in the tables for existing Units 1 through 4 were obtained from EPA’s 

Acid Rain database. Since emissions of N2O and CH4 were not reported before 2010, these GHGs 

were calculated based on the actual annual heat input and emission factors from 40 CFR 98, Subpart 

C. These GHG emissions show the CO2e rates for these pollutants. PSD review is required for GHG 

emissions greater than the listed PSD SER of 75,000 tons CO2e. As shown in Tables 2-9A and 2-9B, 

the maximum potential emission of GHGs will exceed the historical emissions of Units 1 through 4, 

primarily due to greater operation. 
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2.6 Layout, Structures, and Stack Sampling Facilities 

A plot plan of PEEC is presented in Figure 2-1 for the 3-on-1 combined cycle configuration. Northsouth and east-west profiles of the CT/HRSG train are presented in Figures 2-5 and 2-6, respectively. 

The dimensions of the structures are presented in Section 6.0. Stack sampling facilities will be 

constructed in accordance with FDEP Rule 62-297.310(6), F.A.C. 

2.7 Excess Emissions 

Startup and shutdown and fuel changes will require an excess emission allowance greater than the 2 

hours provided under the FDEP rules. During cold startup, the operating load of the CTs is limited by 

the amount of steam that can be accepted by the steam turbine. This will result in excess emissions. 

The same excess emission allowance is requested for PEEC that was authorized for the WCEC 

Project and Cape Canaveral Energy Center (CCEC) Project. The combined cycle units associated 

with these facilities have similar steam turbines that receive steam during startup (i.e., nominal 500 

MW). The proposed condition follows: 

“Excess Emissions Allowed: As specified in this condition, excess emissions 

resulting from startup, shutdown, fuel switching and documented malfunctions are 

allowed provided that operators employ the best operational practices to minimize 

the amount and duration of emissions during such incidents. For each gas 

turbine/HRSG System, excess emissions of NOx and CO resulting from startup, 

shutdown, or malfunction shall be excluded from CEMS data in any 24-hour period 

(“any 24-hour period” means a calendar day, midnight to midnight) for the 

following conditions: (These conditions are considered separate events and each 

event may occur independently within any 24-hour period): 

a. Steam Turbine Cold Startup: For cold startup of the steam turbine, excluded 

emissions from any gas turbine/HRSG system shall not exceed eight hours in 

any 24-hour period. A cold “startup of the steam turbine” is defined as 

startup of the 3-on-1 combined cycle system following a shutdown of the 

steam turbine lasting at least 48 hours. 

{Permitting note: During a cold startup of the steam turbine, each gas turbine/HRSG 

system is sequentially brought on line at low load to gradually increase the 

temperature of the steam-electrical turbine and prevent thermal metal fatigue. Note 

that shutdowns and documented malfunctions are separately regulated in accordance 

with the requirements of this condition.} 

b. Gas Turbine/HRSG System Cold Startup. For cold startup of a gas 

turbine/HRSG system, excluded emissions shall not exceed four hours in any 

24-hour period. “Cold startup of a gas turbine/HRSG system” is defined as a 

startup after the pressure in the high-pressure (HP) steam drum falls below 

450 pounds per square inch gauge (psig) for at least a one-hour period. 
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c. Gas Turbine/HRSG System Warm Startup. For warm startup of a gas 

turbine/HRSG system, excluded emissions shall not exceed two hours in any 

24-hour period. “Warm startup of a gas turbine/HRSG system” is defined as 

a startup after the pressure in the HP steam drum is above 450 psig. 

d. Shutdown Combined Cycle Operation: For shutdown of the combined cycle 

operation, excluded emissions from any gas turbine/HRSG system shall not 

exceed three hours in any 24-hour period. 

e. Gas Turbine/HRSG System Shutdown. For shutdown of the gas 

turbine/HRSG operation, excluded emissions from any gas turbine/HRSG 

system shall not exceed two hours in any 24-hour period. 

f. For fuel switching, excluded emissions shall not exceed 2 hours in any 

24-hour period for each fuel switch and no more than four hours in any 

24-hour period for any gas turbine/HRSG system. 

g. Documented Malfunction. For the gas turbine/HRSG system, excess 

emissions of NOx and CO resulting from documented malfunctions shall not 

exceed two hours in any 24-hour period. A "documented malfunction" means 

a malfunction that is documented within one working day of detection by 

contacting the Compliance Authority by telephone, facsimile transmittal, or 

electronic mail. 

2.8 Proposed Permitted Capacity and Emission Limits 

As discussed previously, the MPS “J” CTs, and the Siemens “H” CTs were used to evaluate the air 

emissions and impacts of the Project. The CT vendor has not been selected. However, FPL desires to 

obtain guarantees of CT performance that will achieve the gross generation of the MPS “J” CT while 

achieving emissions within the range of the emissions provided for the MPS “J” and Siemens “H”. 

As a result, FPL requests consideration of the following permit conditions for permitted capacity and 

emission limits that encompass the CTs being considered. Please note that the Conditions are similar 

in form to those authorized for the FPL Riviera Beach Energy Center (Permit No. 0990042-006-AC). 

Permitted Capacity – Combustion Turbine-Electric Generators (CTG): The maximum heat input rate 

to each CTG is 2,580 mmBtu per hour when firing natural gas and 2,353 mmBtu per hour when firing 

distillate fuel oil (based on a compressor inlet air temperature of 59° F, LHV, of each fuel, no 

evaporative cooling and 100% load). Heat input rates will vary depending upon CTG characteristics, 

ambient conditions, alternate methods of operation, and evaporative cooling. The permittee shall 

provide manufacturer’s performance curves (or equations) that correct for site conditions to the 

Permitting and Compliance Authorities within 90 days of final selection of the CT vendor. Operating 

and emissions data may be adjusted for the CT selected in accordance with the performance curves 

and/or equations submitted to the Department provided the total emissions from the PEEC Project 
January 2012 2-10 113-87618 

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with the CT selected does not trigger review under the Department’s Rule 62-212.400 F.A.C. for any 

pollutant for which there is an emission limit in Condition 10. 

Emissions Standards: Emissions from each CT/HRSG shall not exceed the following standards 

developed under state implementation plan (SIP) permitting procedures. Compliance with these limits 

also assures compliance with the emission limitations in 40 CFR 60, Subpart KKKK. 

Pollutant Fuel 

Method of 

Operation 

Initial Stacks Tests CEMS Rolling Average Limit 

ppmvda ppmvda

 lb/hrb

COd

Oil 

CT Normal 

Mode 

35.0 195.3 35.0, 30 unit operating daysc,d

Gas 9.0 56.7 9.0, 30 unit operating daysc,d

NOx

c

Oil 8.0 84.6 8.0, 30 unit operating daysc,d

Gas 2.0 20.5 2.0, 30 unit operating daysc,d

VOCf

Oil 10.0 37.0 

NA Gas 1.0 3.6 

NH3

g

 Oil/Gas CT, All Modes 5 NA NA 

SAM/SO2

h

Oil/Gas All Modes 

2 gr S/100 SCF of gas, 0.0015% sulfur fuel oil. 

Visible emissions shall not exceed 10% opacity for each 6-

PM/PM10 minute block average. i

a. Concentration standards are given in terms of parts per million, by volume, dry at 15 percent 

oxygen and abbreviated as ppmvd. 

b. The mass emission rate standards in pounds per hour (lb/hr) are based on a turbine inlet 

condition of 59° F, no evaporative cooling, and 100% load, and may be adjusted to actual test 

conditions in accordance with the performance curves and/or equations filed with the 

Department. 

c. “Unit operating day” means a 24-hour period between 12 midnight and the following midnight 

during which any fuel is combusted at any time in the unit. It is not necessary for fuel to be 

combusted continuously for the entire 24-hour period. [40 CFR 60.4420] 

d. Compliance with the continuous 30-unit operating days rolling CO standard shall be 

demonstrated based on data collected by the required CEMS. The initial EPA Method 10 tests 

associated with the certification of the CEMS instruments shall also be used to demonstrate initial 

performance guarantees for natural gas and oil. 

2.9 Construction Boilers 

Temporary construction boilers, rated at up to approximately 150 MMBtu/hr, will be brought onsite 

for use only during the construction of PEEC. The boilers will provide steam for HRSG cleaning and 
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associated steam blows. Each boiler will be fired with natural gas only and is expected to operate for 

no more than 1,500 hr/yr. The boilers will be permanently shut down and removed once PEEC 

commences commercial operation. As these boilers will have no effect on the total Project emissions 

once commercial operation commences, their emissions are not included in any of the Project 

emissions summary tables. However, these boilers are fully described as Emission Unit 7 in the 

attached air application forms. If the PEEC auxiliary boiler is constructed and available for use 

during the construction period where steam is required, one or both temporary boilers may not be 

needed. 
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3.0 AIR QUALITY REVIEW REQUIREMENTS AND APPLICABILITY 

The following discussion pertains to federal, state, and local air regulatory requirements and their 

applicability to PEEC. 

3.1 National, State, and Local AAQS 

The existing applicable national and Florida local AAQS are presented in Table 3-1. Primary 

national AAQS were promulgated to protect the public health with an adequate margin of safety and 

secondary national AAQS were promulgated to protect the public welfare from any known or 

anticipated adverse effects associated with the presence of pollutants in the ambient air. Areas of the 

country in compliance with AAQS are designated as attainment areas. New sources to be located or 

modified sources located in or near these areas may be subject to more stringent air permitting 

requirements. 

3.2 PSD Requirements 

3.2.1 General Requirements

Under federally approved Florida PSD review requirements, all major new or modified sources of air 

pollutants regulated under the Clean Air Act (CAA) must be reviewed and a pre-construction permit 

issued. 

PSD is applicable to a “major facility” and certain “modifications” that occur at a major facility. 

A major facility is defined as any 1 of 28 named source categories that have the potential to emit 

100 TPY or more, or any other stationary facility that has the potential to emit 250 TPY or more, of 

any pollutant regulated under the CAA. “Potential to emit” means the capability, at maximum design 

capacity, to emit a pollutant after the application of control equipment. Net emission increases from a 

modification at a major facility that exceed the PSD SERs are also subject to PSD review. 

EPA has promulgated regulations providing that certain increases above an air quality baseline 

concentration level of SO2, PM10, and NO2 concentrations that would constitute significant 

deterioration. The EPA class designations and allowable PSD increments are presented in Table 3-1. 

Florida has adopted the EPA class designations and allowable PSD increments for SO2, PM10, and 

NO2. 
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PSD review is used to determine whether significant air quality deterioration will result from the new 

or modified facility. Florida’s PSD regulations are found in FDEP Rule 62-212.400, F.A.C. Major 

new facilities and major modifications are required to undergo the following analysis related to PSD 

for each pollutant emitted in significant amounts (see Table 3-2): 

1. Control technology review, 

2. Source impact analysis, 

3. Air quality analysis (monitoring), 

4. Source information, and 

5. Additional impact analyses. 

In addition to these analyses, a new major facility or major modification made to an existing major 

facility also must be reviewed with respect to Good Engineering Practice (GEP) stack height 

regulations. Discussions concerning each of these requirements for a new major facility or major 

modification are presented in the following sections. It is important to note that the emission 

reductions available from the retirement of the existing Units 1 through 4 allow PEEC to be a minor 

modification, exempt from PSD review for all regulated air pollutants except GHG (see Sections 2.4 

and 3.5). 

3.2.2 Greenhouse Gases

On June 3, 2010, EPA issued a ”Tailoring Rule” that “tailors” the applicability provisions of the PSD 

and Title V programs to enable EPA and state agencies to phase in permitting requirements for 

GHGs. The first phase of the Tailoring Rule began on January 2, 2011, and continued through June 

30, 2011. During this period GHG sources became subject to PSD if the increase in GHG emissions 

from a project exceeded 75,000 TPY of CO2e or more and the project was required to undergo PSD 

review for other air regulated pollutants. The second phase of the Tailoring Rule began on July 1, 

2011, and continues thereafter for new major GHG emitting facilities and major modifications. New 

major sources with the potential to emit 100,000 TPY CO2e or more of GHG will be considered 

major sources for PSD permitting purposes and are required to undergo PSD review. Additionally, 

any physical change or change in the method of operation at a major source resulting in a net GHG 

emissions increase of 75,000 TPY CO2e or more will be subject to PSD review. 

For PSD purposes, GHGs are a single air pollutant defined as the aggregate group of the following six 

gases: CO2, N2O, CH4, HFCs, PFCs, and SF6. 
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Once major sources become subject to PSD, these sources must meet the various PSD requirements 

in order to obtain a PSD permit. However, there are no ambient air quality standards or PSD 

increments for GHGs. Therefore, the requirements for a source impact analysis, air quality analysis 

(monitoring), and additional impact analyses are not required. PSD review for GHGs principally 

involves the control technology review that includes a determination of BACT. The EPA published 

the PSD and Title V permitting guidance for GHGs in March 2011 that provides guidance on BACT 

analyses for GHG emissions. 

3.2.3 Control Technology Review

A new major facility or major modification must perform a control technology review, which requires 

that all applicable federal and state emission limiting standards be met and that BACT be applied to 

control emissions from the source (FDEP Rule 62-212.400, F.A.C.). The BACT requirements are 

applicable to all regulated pollutants for which the increase in emissions from the facility or 

modification exceeds the SER (see Table 3-2). 

BACT is defined in FDEP Rule 62-210.200(40), F.A.C., as: 

(a) An emission limitation, including a visible emissions standard, based on the 

maximum degree of reduction of each pollutant emitted, which the 

Department, on a case-by-case basis, determines is achievable through 

application of production processes and available methods, systems and 

techniques (including fuel cleaning or treatment or innovative fuel 

combustion techniques) for control of each such pollutant taking into 

account: 

1. Energy, environmental and economic impacts, and other costs, 

2. All scientific, engineering, and technical material and other 

information available to the Department, and 

3. The emission limiting standards or BACT determinations of Florida 

and any other State. 

(b) If the Department determines that technological or economic limitations on 

the application of measurement methodology to a particular part of an 

emissions unit or facility would make the imposition of an emission standard 

infeasible, a design, equipment, work practice, operational standard or 

combination thereof, may be prescribed instead to satisfy the requirement for 

the application of BACT. Such standard shall, to the degree possible, set 

forth the emissions reductions achievable by implementation of such design, 

equipment, work practice or operation. 

(c) Each BACT determination shall include applicable test methods or shall 

provide for determining compliance with the standard(s) by means which 

achieve equivalent results. 
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(d) In no event shall application of best available control technology result in 

emissions of any pollutant which would exceed the emissions allowed by any 

applicable standard under 40 CFR Parts 60, 61, and 63. 

The BACT requirements are intended to ensure that the control systems incorporated in the design of 

a proposed facility reflect the latest in control technologies used in a particular industry and take into 

consideration existing and future air quality in the vicinity of the proposed facility. BACT must, at a 

minimum, demonstrate compliance with NSPS for a source (if applicable). An evaluation of the air 

pollution control techniques and systems, including a cost-benefit analysis of alternative control 

technologies capable of achieving a higher degree of emission reduction than the proposed control 

technology, is required. The cost-benefit analysis requires the documentation of the materials, 

energy, and economic penalties associated with the proposed and alternative control systems, as well 

as the environmental benefits derived from these systems. A decision on BACT is to be based on 

sound judgment, balancing environmental benefits with energy, economic, and other impacts (EPA, 

1978). 

For GHG emissions, control technology review is conducted by EPA under its regulations in 40 CFR 

52.21. EPA issued guidance on the determination of BACT for GHGs (“PSD and Title V Permitting 

Guidance for Greenhouse Gases”, March 2011). This EPA guidance supplements previous EPA 

guidance on the determination of BACT that is specific to BACT determinations for GHG emissions. 

3.2.4 Source Impact Analysis

A source impact analysis must be performed for a new major facility or major modification to a major 

source for each pollutant, subject to PSD review, for which net emissions exceed the SER 

(Table 3-2). The PSD regulations specifically provide for the use of atmospheric dispersion models 

in performing impact analyses, estimating baseline and future air quality levels, and determining 

compliance with AAQS and allowable PSD increments. Designated EPA models that are approved 

by FDEP normally must be used in performing the impact analysis. Specific applications for other 

than EPA approved models require EPA’s consultation and prior approval. Guidance for the use and 

application of dispersion models is presented in the EPA publication Guideline on Air Quality Models 

(Revised). The source impact analysis for criteria pollutants to address compliance with AAQS and 

PSD Class II increments may be limited to the new source if the impacts as a result of the new source 

are below significant impact levels, as presented in Table 3-1. 
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The EPA has proposed significant impact levels for Class I areas. Although these levels have not 

been officially promulgated as part of the federal PSD regulations and may not be binding for states 

in performing PSD reviews, the levels serve as a guideline in assessing a source’s impact in a Class I 

area. FDEP has accepted the use of these significant impact levels. 

Various lengths of meteorological data records can be used for impact analysis. A 5 year period can 

be used with corresponding evaluation of highest, second highest short term concentrations for 

comparison to AAQS or PSD increments. The term “highest, second highest” (HSH) refers to the 

highest of the second highest concentrations at all receptors (i.e., the highest concentration at each 

receptor is discarded). The second highest concentration is significant because short term AAQS 

specify that the standard should not be exceeded at any location more than once a year. If fewer than 

5 years of meteorological data are used in the modeling analysis, the highest concentration at each 

receptor normally must be used for comparison to air quality standards. 

Because there are no AAQS or PSD increments applicable to GHG emissions, these analyses are not 

conducted for PSD review for GHG. 

3.2.5 Air Quality Monitoring Requirements

In accordance with requirements of FDEP Rule 62-212.400(5)(f), F.A.C., PSD review for a new 

major facility or major modification must consider an analysis of continuous ambient air quality data 

in the area affected by the proposed major PSD source or major modification. For a new major 

facility or major modification, the affected pollutants are those that the facility potentially would emit 

above the SERs. 

Ambient air monitoring for a period of up to 1 year generally is appropriate to satisfy the PSD 

monitoring requirements. Data for a minimum of 4 months are required. Existing data from the 

vicinity of the proposed source may be used, if the data meet certain quality assurance requirements; 

otherwise, additional data may need to be gathered. Guidance in designing a PSD monitoring 

network is provided in Ambient Monitoring Guidelines for Prevention of Significant Deterioration

(EPA, 1987a). 

The regulations include an exemption that excludes or limits the pollutants for which an air quality 

analysis must be conducted. This exemption states that a proposed major stationary facility is exempt 

from the monitoring requirements with respect to a particular pollutant, if the emissions of the 
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pollutant from the facility would cause, in any area, air quality impacts less than the de minimis levels 

presented in Table 3-2 (FDEP Rule 62-212.400-3, F.A.C.). If a facility’s predicted impacts are less 

than the de minimis levels, then preconstruction monitoring is not required. 

Because there are no ambient monitoring methods applicable to GHG emissions, these analyses are 

not conducted for PSD review for GHG. 

3.2.6 Source Information/GEP Stack Height

Source information must be provided to adequately describe the proposed facility or major 

modification subject to PSD review. 

The 1977 CAA Amendments require that the degree of emission limitation required for control of any 

pollutant cannot be affected by a stack height that exceeds GEP or any other dispersion technique. 

On July 8, 1985, EPA promulgated final stack height regulations (EPA, 1985a). Identical regulations 

have been adopted by FDEP (FDEP Rule 62-210.550, F.A.C.). GEP stack height is defined as the 

highest of: 

1. 65 meters; or 

2. A height established by applying the formula: 

 Hg = H + 1.5 L 

 where: 

 Hg = GEP stack height, 

 H = Height of the structure or nearby structure, and 

L = Lesser dimension (height or projected width) of 

nearby structure(s); or 

3. A height demonstrated by a fluid model or field study. 

“Nearby” is defined as a distance up to 5 times the lesser of the height or width dimensions of a 

structure or terrain feature, but not greater than 0.8 kilometer (km). Although GEP stack height 

regulations require that the stack height used in modeling for determining compliance with AAQS 

and PSD increments not exceed the GEP stack height, the actual stack height may be greater. 

The stack height regulations also allow increased GEP stack height beyond that resulting from the 

above formula in cases where plume impaction occurs. Plume impaction is defined as concentrations 
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measured or predicted to occur when the plume interacts with elevated terrain. Elevated terrain is 

defined as terrain that exceeds the height calculated by the GEP stack height formula. 

3.2.7 Additional Impact Analysis

In addition to air quality impact analyses, Florida PSD regulations require analyses for applicable 

pollutants of the impairment to visibility and the impacts on soils and vegetation that would occur as a 

result of a new major facility or major modification subject to PSD review [FDEP 

Rule 62-212.400(5)(e), F.A.C.]. Impacts as a result of general commercial, residential, industrial, and 

other growth associated with the source also must be addressed. These analyses are required for each 

pollutant emitted in significant amounts (see Table 3-2). 

Because GHG emissions will not cause visibility impairment or direct impacts to soils and vegetation, 

these analyses are not conducted for PSD review for GHG. 

3.2.8 Air Quality Related Values

An Air Quality Related Value (AQRV) analysis is required for projects for those pollutants 

undergoing PSD review to assess the potential impact on AQRVs in PSD Class I areas. The nearest 

Class I areas to PEEC are the Everglades National Park (NP), located about 50 km (30 miles) from 

PEEC, and the Chassahowitzka National Wilderness Area (NWA), located more than 300 km 

(180 miles) from PEEC. The U.S. Department of the Interior in 1978 administratively defined 

AQRVs to be: 

All those values possessed by an area except those that are not affected by changes in 

air quality and include all those assets of an area whose vitality, significance, or 

integrity is dependent in some way upon the air environment. These values include 

visibility and those scenic, cultural, biological, and recreational resources of an area 

that are affected by air quality. 

Important attributes of an area are those values or assets that make an area 

significant as a national monument, preserve, or primitive area. They are the assets 

that are to be preserved if the area is to achieve the purposes for which it was set 

aside (Federal Register, 1978). 

The AQRVs include visibility, freshwater and coastal wetlands, dominant plant communities, unique 

and rare plant communities, soils and associated periphyton, and the wildlife dependent on these 

communities for habitat. Rare, endemic, threatened, and endangered species of the NP and 

bioindicators of air pollution (e.g., lichens) must also be evaluated. 
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3.3 Nonattainment Rules 

FDEP has nonattainment provisions (FDEP Rule 62-212.500, F.A.C.) that apply to all new major 

facilities or major modifications to major facilities located in a nonattainment area. In addition, for 

these facilities that are located in an attainment or unclassifiable area, the nonattainment review 

procedures apply if the source or modification is located within the area of influence of a 

nonattainment area. PEEC is located in Broward County, which is classified as an attainment area for 

all criteria pollutants. Therefore, nonattainment New Source Review (NSR) requirements are not 

applicable. 

3.4 Emission Standards 

3.4.1 New Source Performance Standards

The NSPS are a set of national emission standards that apply to specific categories of new sources. 

As stated in the 1977 CAA Amendments, these standards “shall reflect the degree of emission 

limitation and the percentage reduction achievable through application of the best technological 

system of continuous emission reduction the Administrator determines has been adequately 

demonstrated.” 

PEEC will be subject to one or more NSPS. EPA promulgated new NSPS for Stationary Combustion 

Turbines that will commence construction after February 18, 2005. Subpart KKKK replaces Subpart 

GG for CTs. On October 15, 2003, EPA promulgated changes to 40 CFR 60, Subpart Kb that would 

exempt light oil tanks containing No. 2 light oil by virtue of its vapor pressure (FR Vol. 68, No. 199, 

Pages 59328-59333). 

Combustion Turbine 

NOx and SO2 emissions from all stationary CTs with a heat input at peak load equal to 10.7 gigajoules 

per hour (10 MMBtu/hr), based on the lower heating value of the fuel fired, are limited per 40 CFR 

60 Subpart KKKK. NOx emissions for these proposed CTs (i.e., >850 MMBtu/hr) are limited by 

Subpart KKKK to 15 ppmvd corrected to 15 percent O2 and 42 ppmvd corrected to 15 percent O2 for 

natural gas and oil firing, respectively. SO2 emissions are limited to using a fuel with a sulfur content 

of no greater than 0.05 percent and 20 gr/10 scf of sulfur for oil and natural gas firing, respectively. 

In addition to emission limitations, there are requirements for performance testing and monitoring in 

40 CFR 60 Subpart KKKK. 
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Subpart KKKK is also applicable to the turbines associated with the natural gas compressors. These 

turbines will fire only natural gas with heat input greater than 50 MMBtu/hr but less than 850 

MMBtu/hr. NOx emissions for these turbines are limited by Subpart KKKK to 25 ppmvd corrected to 

15 percent O2. 

There are also applicable notification, reporting, and recordkeeping requirements in the general 

provisions of 40 CFR 60 Subpart A. These are summarized below:

40 CFR 60.7 Notification and Record Keeping 

 (a)(1) Notification of the date of construction - 30 days after such date. 

 (a)(3) Notification of actual date of initial startup - within 15 days after such date. 

 (a)(5) Notification of date which demonstrates CEM - not less than 30 days prior to 

date 

60.7 (b) Maintain records of all startups, shutdowns, and malfunctions. 

(c) Excess emissions reports – semi-annually by the 30th day following 6-month 

period (required even if no excess emissions occur). 

(d) Maintain file of all measurements for 2 years. 

60.8 Performance Tests 

(a) Must be performed within 60 days after achieving maximum production rate, 

but no later than 180 days after initial startup. 

(d) Notification of Performance tests at least 30 days prior to them occurring. 

Other Emission Units 

NSPS are also applicable to the auxiliary boiler, fuel heaters, fire pump engine, and emergency 

generators. The EPA NSPS Subpart Dc, Standards of Performance for Small Industrial-CommercialInstitutional Steam Generating Units, applies to the auxiliary boiler and fuel heaters. For the 

emergency generators and fire pump engine, NSPS Subpart IIII, Standards of Performance for 

Stationary Compression Ignition Internal Combustion Engines, is applicable. 

3.4.2 National Emission Standards for Hazardous Air Pollutants

EPA has promulgated maximum achievable control technology (MACT) standards under the National 

Emissions Standards for Hazardous Air Pollutants (NESHAPs) regulations. Maximum annual 

potential HAPs emissions were presented earlier in Table 2-10 for the MPS “J” CTs and Siemens “H” 

CTs. Additional detail on the HAP emission calculations is also presented in Appendices A and B. 
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The Port Everglades Plant remains a major source of HAPs due to the combined emissions of PEEC 

and the existing 12 gas turbines. Therefore, certain MACT standards under the NESHAP regulations 

would apply. Under the NESHAPs of 40 CFR Part 63, Subpart YYYY applies to the CTs and 

Subpart ZZZZ applies to the reciprocating internal combustion engines (RICE). 

3.4.3 Florida Rules

FDEP has adopted the EPA NSPS by reference in FDEP Rule 62-204.800(7): Subsection (b)39 for 

stationary gas turbines and Subsection (b)16 for volatile organic liquid storage vessels. Therefore, the 

facility is required to meet the same emissions, performance testing, monitoring, reporting, and record 

keeping as those described in Section 3.4.1. FDEP has authority for implementing NSPS 

requirements in Florida. 

3.4.4 Florida Air Permitting Requirements

The FDEP regulations require any new source to obtain an air permit prior to construction. Major 

new sources must meet the appropriate PSD and nonattainment requirements as discussed previously. 

Required permits and approvals for air pollution sources include NSR for nonattainment areas, PSD, 

NSPS, NESHAP, Permit to Construct, and Permit to Operate. The requirements for construction 

permits and approvals are contained in FDEP Rules 62-4.030, 62-4.050, 62-4.210, 62-210.300(1), and 

62-212.400, F.A.C. Specific emission standards are set forth in Chapter 62-296, F.A.C. 

This Application is being filed for the purpose of establishing federally enforceable emission 

limitations that ensure the Project will not result in a significant net increase in emissions of any 

regulated air pollutant, in accordance with FDEP’s federally approved minor source air construction 

permit program under Florida’s federally approved SIP. 

3.4.5 Local Air Regulations

The Pollution Prevention, Remediation and Air Quality Division (PPRAQD) of Broward County is 

the air compliance authority for the County, implementing FDEP regulations. PPRAQD has been 

delegated authority to review, process, and take appropriate action (i.e., exempt, issue, or deny) on 

most FDEP District-Level permits within the County. However, permits for electrical power plants 

are issued by FDEP, and PPRAQD provides review of the application during FDEP’s review period. 
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3.5 Source Applicability 

3.5.1 Area Classification

PEEC is located in Broward County, which has been designated by EPA and FDEP as an attainment 

area (includes unclassifiable) for all criteria pollutants. Broward County and surrounding counties are 

designated as PSD Class II areas for SO2, PM [total suspended particulate (TSP)], and NO2. The 

nearest Class I area to PEEC is the Everglades NP, located approximately 50 km (30 miles) from the 

Site, and Chassahowitzka NWA, located more than 300 km (180 miles) from PEEC. 

3.5.2 PSD Review

Pollutant Applicability 

Since the existing Units 1 through 4 will be permanently retired, FPL will use emissions reductions 

from these units to net out of PSD review for all PSD pollutants, except GHG, for PEEC (see Tables 

2-9A and 2-9B in Section 2.0 and Table 3-3). The Project is a modification of the existing Units 1 

through 4 as a major source of GHGs. While the GHG emission rate for PEEC will be less than half 

the rate for the existing Units 1 through 4, PPEC will have a net GHG emissions increase above the 

threshold for modifications. This is primarily due to the lower capacity factor on the existing Port 

Everglades Units 1 through 4 of about 29 percent compared to the 100 percent capacity assumed for 

PEEC. As a result, PEEC will exceed the GHG PSD threshold, and PSD review by EPA is required. 

Section 4.3.1 presents a BACT analysis for GHGs for the PEEC Project. (Note: EPA no longer 

requires PSD review for HAPs.) The pollutants vinyl chloride, asbestos, and beryllium are no longer 

evaluated in PSD review because they are addressed through the NESHAP program. 

Emission Standards 

NOx and SO2 emissions from all stationary CTs with a heat input at peak load equal to 10.7 gigajoules 

per hour (10 MMBtu/hr), based on the lower heating value of the fuel fired, are limited per 40 CFR 

60 Subpart KKKK adopted by reference by FDEP in Rule 62-204.800(8)(b)78 F.A.C.. NOx

emissions for these proposed CTs (i.e., >850 MMBtu/hr) are limited by Subpart KKKK to 15 ppmvd 

corrected to 15 percent O2 and 42 ppmvd corrected to 15 percent O2 for natural gas and oil firing, 

respectively. SO2 emissions are limited to using a fuel with a sulfur content of no greater than 0.05 

percent and 20 gr/100 scf of sulfur for oil and natural gas firing, respectively. These requirements are 

summarized in Section 4.2. In addition to emission limitations, there are requirements for 

performance testing and monitoring in 40 CFR 60 Subpart KKKK. There are also applicable 

notification, reporting, and recordkeeping requirements in the general provisions of 40 CFR 60 
January 2012 3-12 113-87618 

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Subpart A. The proposed emissions for PEEC will be well below the specified limits (see Section 

4.0). 

Subpart KKKK is also applicable to the turbines associated with the natural gas compressors. These 

turbines will fire only natural gas with heat input greater than 50 MMBtu/hr but less than 850 

MMBtu/hr and the Subpart KKKK NOx emissions limit is 25 ppmvd corrected to 15 percent O2. For 

PEEC, the proposed NOx emissions rate of 15 ppmvd corrected to 15 percent O2 is well below the 

Subpart KKKK limit. 

NSPS are also applicable to the auxiliary boiler, fuel heater, fire pump engine, and emergency 

generators. The EPA NSPS Subpart Dc, Standards of Performance for Small Industrial-CommercialInstitutional Steam Generating Units, applies to the auxiliary boiler and fuel heaters [adopted by 

FDEP by reference in Rule 62-204.800(8)(b)4 F.A.C.]. For the emergency generators and fire pump 

engine, NSPS Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal 

Combustion Engines, is applicable [adopted by FDEP by reference in Rule 62-204.800(8)(b)79 

F.A.C.]. 

EPA has promulgated MACT standards under the NESHAP regulations and applicability is based on 

whether a source is major or minor for HAPs. A facility is classified as a major source of HAPs when 

the maximum potential emissions for all emission units located at the facility exceed 10 TPY of a 

single HAP and 25 TPY for all HAPs. The Port Everglades Plant will remain a major source of HAPs 

due to the combined potential emissions of PEEC along with the 12 existing gas turbines.. 

The NESHAP Subpart YYYY applies to PEEC if the aggregate use of oil by existing and new 

turbines exceeds 1,000 hours during any calendar year. However, information available from the 

equipment vendors indicate that PEEC will meet the proposed MACT of 91 parts per billion by 

volume dry (ppbvd) corrected to 15 percent O2 for formaldehyde. FDEP adopted this EPA rule by 

reference in Rule 62-204.800(11)(b)81 F.A.C. 

The NESHAP Subpart ZZZZ addressing RICE applies to both major and area sources of HAPs. 

FDEP adopted this EPA rule by reference in Rule 62-204.800(11)(b)82 F.A.C. The method of 

compliance under this rule is demonstrating compliance with 40 CFR 60, Subpart IIII, which was 

previously cited in this section. The emergency generators and fire pump engine will meet the 

requirements of Subpart III. 
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Ambient Monitoring 

For PEEC, the net emissions changes will be less than the PSD SERs. As a result, an air quality 

monitoring impact analysis is not required by NSR under FDEP air regulations. As a supplement to 

the air permit application, air quality monitoring data are provided, which demonstrate that Broward 

County is in attainment of the AAQS for all criteria pollutants. These data are presented in Section 

5.0 of this application. 

GEP Stack Height Impact Analysis 

The GEP stack height regulations allow any stack to be at least 65 meters (213 ft) high. The HRSG 

stacks will be 149 ft. These stack heights do not exceed the GEP stack height. However, as 

discussed in Section 6.0, Air Quality Modeling Approach, since the stack height is less than GEP, 

building downwash effects must be considered in the modeling analysis. As a result, the potential for 

downwash of the CT emissions caused by nearby structures is included in the modeling analysis. 

In addition, since the stack heights for the other PEEC sources are also less than GEP, building 

downwash effects were included in the modeling analysis for these sources. 

3.5.3 Local Air Regulations

As specified in Subsection 3.4.5, PPRAQD does not have delegated authority to review, process, or 

take appropriate action over electrical power plant projects; therefore, permitting requirements for 

PEEC will comply with FDEP permitting requirements. 

3.5.4 Other Clean Air Act Requirements

The 1990 CAA Amendments established a program to reduce potential precursors of acidic 

deposition. The Acid Rain Program was delineated in Title IV of the CAA Amendments and required 

EPA to develop the program. EPA’s final regulations were promulgated on January 11, 1993, and 

included permit provisions (40 CFR 72), allowance system (Part 73), continuous emission monitoring 

(CEM) (Part 75), excess emission procedures (Part 77), and appeal procedures (Part 78). FDEP 

adopted these rules by reference in Rule 62-204.800(16) F.A.C. (permit provisions), Rule 62-

204.800(17) F.A.C. (allowance system), Rule 62-204.800(19) F.A.C.[ continuous emission 

monitoring (CEM)], Rule 62-204.800(21) F.A.C. (excess emission procedures), and Rule 62-

204.800(22) F.A.C. (appeal procedures). 
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EPA’s Acid Rain Program applies to all existing and new utility units, except those serving a 

generator less than 25 MW, existing simple cycle CTs, and certain non-utility facilities; units which 

fall under the program are referred to as affected units. The EPA regulations are applicable to PEEC 

for the purposes for obtaining a permit and allowances, as well as emission monitoring. New units 

are required to obtain permits under the program by submitting a complete application 24 months 

before the date on which the unit commences operation (e.g., first fire). 

The permit would require the units to hold SO2 emission allowances. Emission limitations 

established in the Acid Rain Program are presumed to be less stringent than BACT for new units. An 

allowance is a market based financial instrument that is equivalent to 1 ton of SO2 emissions. 

Allowances can be sold, purchased, or traded. 

CEM for NOx is required for natural gas-fired and oil-fired affected units. SO2 monitoring is also 

required, although use of CEM is optional. When an SO2 CEM system is selected to monitor SO2

mass emissions, a flow monitor is also required. Alternately, SO2 emissions may be determined using 

procedures established in Appendix D, 40 CFR 75 (FDEP Rule 62-204.800(19)(b)4 F.A.C.; flow 

proportional oil sampling or manual daily oil sampling). CO2 emissions must also be determined 

either through a CEM (e.g., as a diluent for NOx monitoring) or calculation. Alternate procedures, 

test methods, and quality assurance/quality control (QA/QC) procedures for CEM are specified (Part 

75, Appendices A through I; FDEP Rule 62-204.800(19)(b)1-9 F.A.C.). The acid rain CEM 

requirements including QA/QC procedures are, in general, more stringent than those specified in the 

NSPS for Subpart KKKK. New units are required to meet the requirements by not later than 90 days 

after the unit commences commercial operation. 
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4.0 CONTROL TECHNOLOGY DESCRIPTION 

4.1 Applicability 

The PSD regulations require new major stationary sources or major modifications to existing major 

sources to undergo a control technology review for each pollutant that may potentially be emitted 

above significant amounts. As discussed in previous sections, PSD review is required for PEEC for 

GHG; for other regulated pollutants, PSD review is not required and the control technology review 

requirements of the PSD regulations are not applicable. 

There are NSPS regulations which are applicable to NOx and SO2. In addition, there are also minor 

emissions of PM/PM10, CO and VOCs as a result of the combustion of natural gas and ULSD oil. 

Notwithstanding, the emission levels and control technologies proposed for these pollutants are 

consistent with emission levels established as BACT by the FDEP in recent projects. Subsection 4.2 

presents an overview of the control technology and applicable NSPS, and the control technology for 

minimizing emissions of NOx, CO, SO2 and sulfuric acid mist, PM/PM10, and VOCs. Section 4.3 

presents the BACT analysis for GHGs. 

4.2 Overview of Control Technology and Applicable NSPS 

The use of clean fuels (natural gas and ULSD oil), combustion controls, and air pollution control 

equipment will minimize air emissions and ensure compliance with applicable emission-limiting 

standards. Using clean fuels will minimize emissions of SO2, PM/PM10, and other fuel bound 

contaminants. Combustion controls will minimize the formation of NOx and the formation of CO and 

VOCs by combustor design. Further NOx reduction will be achieved by SCR. The combination of 

these techniques has been determined to represent BACT on previous projects based on an evaluation 

of economic, energy, and environmental impacts. The following subsection presents a summary of 

the Air Pollution Control Technology proposed for PEEC. 

EPA updated NSPS for Stationary Combustion Turbines that will commence construction after 

February 18, 2005. Subpart KKKK (Rule 62-204.800(8)(b)78 F.A.C.) applies to units with a heat 

input at peak load of 10 MMBtu/hr. The Subpart KKKK emissions requirements applicable to 

combustion turbines greater than 30 MW apply to CT/HRSG trains associated with PEEC. The NOx

emissions are limited to 15 ppm corrected to 15 percent O2 or 0.43 lb/MW-hr for natural gas firing 

and 42 ppm corrected to 15 percent O2 or 1.3 lb/MW-hr for light oil firing. For PEEC, the NOx

emissions are limited to 2 ppm corrected to 15 percent O2 and less than 0.05 lb/MW-hr when natural 
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gas firing. For SO2 emissions, Subpart KKKK requirements limit emissions to 0.9 lb/MW-hr or a 

potential total sulfur content equivalent to 0.06 lb/MMBtu if multiple fuels are fired. For PEEC the 

SO2 emissions are less than 0.04 lb/MW-hr when firing natural gas and 0.02 lb/MW-hr when firing 

ULSD oil. 

Table 4-1 presents the proposed emission limits for PEEC. The proposed GHG BACT emission limit 

applicable to EPA regulations is discussed in Section 4.3. 

NSPS are also applicable to the gas compressor turbines, auxiliary boiler, fuel heaters, emergency 

generators, and fire pump engine. Subpart KKKK is applicable to the gas compressor turbines with a 

Subpart KKKK NOx emissions limit of 25 ppmvd corrected to 15 percent O2 compared to a proposed 

NOx emissions rate for PEEC of 15 ppmvd corrected to 15 percent O2. The EPA NSPS Subpart Dc, 

Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units, 

applies to the auxiliary boilers and fuel heaters. For the emergency generators and fire pump engine, 

NSPS Subpart IIII, Standards of Performance for Stationary Compression Ignition Internal 

Combustion Engines, is applicable. 

4.2.1 Nitrogen Oxides

The Project will result in a net emissions decrease of about 3,900 TPY for NOx emissions (i.e., more 

than 85 percent reduction from historical emissions). PSD review, including a BACT determination, 

is not applicable. However, the NOx control technology and emission limits proposed for PEEC are 

consistent with emission limits established as BACT in Florida and EPA Region IV for similarly 

designed projects. The use of DLN combustors and SCR for PEEC with NOx emission levels of 2 

ppmvd corrected to 15 percent O2 when firing natural gas and 8 ppmvd corrected to 15 percent O2 is 

consistent with recently established BACT emission limits for other combined cycle units when firing 

ULSD oil. Similarly, the NOx emission rates proposed for the auxiliary boiler, natural gas heaters, 

emergency generators, and natural gas compressors have been established as BACT in previous PSD 

permits. 

When firing natural gas, NOx emissions will be controlled using DLN combustors. DLN combustor 

technology has been offered and installed by CT manufacturers to reduce NOx emissions by 

inhibiting thermal NOx formation through premixing fuel and air prior to combustion and providing 

premix combustion to reduce flame temperatures. The DLN combustors have premixed fuel zones 

plus a standard diffusion flame pilot burner for startup. Low NOx levels are achieved by introducing 
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fuel primarily to the premix zones and reducing the amount of fuel being combusted from the pilot 

nozzle. 

NOx emissions will be further controlled by SCR systems when firing either natural gas or ULSD oil. 

SCR is a post combustion process where NOx in the gas stream is reacted with ammonia in the 

presence of a catalyst to form nitrogen and water. The reaction occurs typically between about 320 

and 400 degrees Celsius (°C) (600 and 750°F). These temperatures occur within the HRSG where the 

SCR catalyst and aqueous ammonia injection grid is installed. Aqueous ammonia will be stored 

onsite in tank(s). The SCR system will be designed for additional NOx reduction. Flue gas NOx

emissions when firing natural gas will be reduced to 2 ppmvd, corrected to 15 percent O2. When 

firing ULSD oil, SCR will reduce NOx emissions by 80 percent or more to 8 ppmvd corrected to 15 

percent O2 or less. 

The NOx emissions from the auxiliary boiler, fuel heaters, emergency generators, pump fire engine, 

and natural gas compressors will be limited using combustion techniques. The auxiliary boiler will 

be equipped with low NOx burners to reduce NOx emissions to 0.05 lb/MMBtu (HHV). The fuel 

heaters will use combustion controls to reduce NOx emissions to 0.095 lb/MMBtu (HHV). The 

emergency generators will meet the NSPS Subpart IIII NOx emission requirements of 6.5 grams per 

brake horsepower-hour (g/bhp-hr). The natural gas compressors are based on gas turbines using Solar 

Turbines dry low emissions (DLE) technology or equivalent with a maximum NOx emission rate of 

15 ppmvd corrected to 15 percent O2. 

4.2.2 Carbon Monoxide

The Project will result in a net decrease in CO emissions for the Siemens “H” CTs and a net increase 

in CO emissions for the MPS “J” CTs that will be less than the PSD significant emission rate of 100 

TPY. Therefore, PSD review, including a BACT determination, is not applicable. However, the use 

of combustion controls to reduce CO emissions in the range proposed for natural gas and ULSD oil 

firing has been the technology used to achieve low CO emission rates in CTs. 

The emission rates are based upon the CTs being considered for PEEC. The CTs will utilize 

advanced combustion technology with an expected CO emission rate of 9 ppmvd corrected to 15 

percent O2 at baseload operation when firing natural gas and 35 ppmvd corrected to 15 percent O2

When firing ULSD oil. These CO emission rates envelope the CTs under consideration. 
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Combustion techniques will be used to reduce the CO emissions from the auxiliary boiler, fuel 

heaters, fire pump engine, and emergency generators. The auxiliary boiler will be equipped with low 

NOx burners designed to reduce CO emissions to 0.08 lb/MMBtu. The fuel heaters will use 

combustion controls to reduce CO emissions to 0.08 lb/MMBtu. The emergency generators will meet 

the NSPS Subpart IIII CO emission requirements of 8.5 g/bhp-hr. Each natural gas compressor will 

be equipped with combustion technology to reduce CO emissions to 25 ppmvd corrected to 15 

percent O2. 

The CO emission rates proposed for the auxiliary boiler, fuel heaters, emergency generators, and 

natural gas compressors have also been established as BACT in previous PSD permits. 

4.2.3 Sulfur Oxides (SO2 and H2SO4 Mist)

The Project will result in net emissions decreases of more than 9,000 TPY for SO2 emissions and 

about 380 TPY for sulfuric acid (H2SO4) mist (i.e., reductions of more than 95 percent for SO2 and 

90 percent for H2SO4 from historical emissions). PSD review, including a BACT determination, is 

not applicable. The only feasible control for the combined cycle unit, auxiliary boilers, fuel heaters, 

emergency generators, fire pump engine, and natural gas compressors is combustion of clean fuels. 

Natural gas and ULSD oil are the cleanest fuels available with maximum sulfur contents of 2 gr/100 

scf for natural gas and 0.0015 percent sulfur for ULSD oil proposed for PEEC. H2SO4 emissions will 

also be minimized by the use of low sulfur fuels. SO2 and sulfuric acid mist emission limits based on 

use of natural gas and ULSD oil have been established as BACT in previous PSD permits. 

4.2.4 Particulate Matter and Other Regulated Pollutants

The Project will result in a net emissions decrease of more than 350 TPY for PM/PM10 (i.e., more 

than 50 percent reduction from historical emissions). PSD review, including a BACT determination, 

is not applicable. The use of clean fuels, characterized by low PM and trace contaminant contents 

and advanced combustion techniques, results in negligible PM and PM10 emissions from the 

combined cycle unit, auxiliary boiler, fuel heaters, emergency generators, fire pump engine, and 

natural gas compressors. Emission limits based on the use of clean fuels (i.e., natural gas and ULSD 

oil) have been established as BACT for PM/PM10 emissions in previous PSD permits. 
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4.2.5 Volatile Organic Compound

The Project will result in a net emissions increase of less than 40 TPY for VOC. Therefore, PSD 

review, including a BACT determination, is not applicable. Combustion techniques will be used to 

reduce the VOC emissions from the combined cycle unit, auxiliary boiler, fuel heaters, emergency 

generators, fire pump engine, and natural gas compressors. 

The CTs will utilize advanced combustion technology, and the proposed emission rates are consistent 

with those established as BACT for these turbines. The proposed VOC emission rate for the MPS “J” 

CTs or equivalent when firing natural gas is 1 ppmvd corrected to 15 percent O2 at baseload 

operation. When firing oil, the VOC emissions from the MPS “J” CTs or equivalent will be based on 

10 ppmvd corrected to 15 percent O2. VOC emissions for the Siemens “H” CTs or equivalent will be 

based on 1 ppmvd (corrected to 15 percent O2) when firing natural gas at baseload operation. For the 

Siemens “H” CTs or equivalent when firing oil, the VOC emissions will be based on 10 ppmvd 

corrected to 15 percent O2. 

The auxiliary boiler is designed with proper combustion techniques to reduce VOC emissions to 

0.005 lb/MMBtu. The fuel heaters will use combustion controls to reduce VOC emissions to 

0.005 lb/MMBtu. The emergency generators will meet the NSPS Subpart IIII (Rule 62-

204.800(8)(b)79 F.A.C.) VOC emission requirements of 1 g/bhp-hr as total hydrocarbons. Each 

natural gas compressor will be equipped with combustion technology to reduce VOC emissions to 

12.5 ppmvd corrected to 15 percent O2. 

4.3 GHG Control Technology Review 

This section addresses EPA’s GHG PSD regulations in 40 CFR 52.21. As shown in Tables 2-9A and 

2-9B there will be an increase in GHG emissions based on a comparison of potential emissions from 

PEEC and the baseline actual emissions of the existing Port Everglades Plant Units 1 through 4. As a 

result, this subsection presents a BACT analysis for the PEEC Project. The approach to the BACT 

analysis is based on the regulatory definitions of BACT, as well as consideration of EPA’s current 

guidelines suggesting that a “top-down” approach be followed in BACT analyses. The CAA and 

corresponding implementing regulations require that a BACT analysis be conducted on a case by case 

basis taking into consideration the amount of emissions reductions that each available emissions 

reducing technology or technique would achieve, as well as the energy, environmental, economic and 

other costs associated with each technology or technique. 
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EPA has recommended since 1990 that permitting authorities use the five step “top down” BACT 

process to determine BACT. The top down process calls for all available control technologies for a 

given pollutant to be identified and ranked in descending order of control effectiveness. The permit 

applicant should first examine the highest ranked (“top”) option. The top ranked options should be 

established as BACT unless the permit applicant demonstrates to the satisfaction of the permitting 

authority that technical considerations, or energy, environmental, or economic impacts justify a 

conclusion that the top ranked technology is not “achievable” in that case. If the most effective 

control strategy is eliminated in this fashion, then the next most effective alternative should be 

evaluated, and so on, until an option is selected as BACT. 

EPA has broken down this “top down” process into the following five steps: 

Step 1: Identify all available control technologies 

Step 2: Eliminate technically infeasible options 

Step 3: Rank remaining control technologies 

Step 4: Evaluate most effective controls and document results 

Step 5: Select the BACT 

The Clean Air Act specifies that BACT cannot be less stringent than any applicable standard of 

performance under the NSPS. EPA has not promulgated any NSPS that contain emissions limits for 

GHGs. 

EPA issued guidance on the determination of BACT for GHGs (“PSD and Title V Permitting 

Guidance for Greenhouse Gases”, March 2011). EPA believes that in BACT reviews of GHGs that 

the “top down” approach be followed, but that it is important to consider options that improve the 

overall energy efficiency of the source or modification – through technologies, processes and 

practices at the emitting unit. In general, a more energy efficient technology burns less fuel than a 

less energy efficient technology on a per unit of output basis. Thus, considering the most energy 

efficient technologies in the BACT analysis helps reduce the products of combustion, which includes 

not only GHGs but other regulated NSR pollutants (e.g., NOX, SO2, PM/PM10/PM2.5, CO, etc.). Thus, 

EPA emphasizes that energy efficiency should be considered in BACT determinations for all 

regulated NSR pollutants (not just GHGs). 

The following subsections provide the BACT analysis for the PEEC Project. 
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4.3.1 BACT Analysis for PEEC – 3-on-1 Combined Cycle Unit

The BACT analysis for the GHG emissions from the PEEC combined cycle unit followed the EPA 

suggested 5 step “top down” process: 

Step 1 – Identify All Available Control Technologies 

The first step in the top down BACT process is to identify all “available” control options. Available 

control options are those air pollution control technologies or techniques (including lower emitting 

processes and practices) that have the potential for practical application to the emissions unit and the 

regulated pollutant under evaluation. 

EPA has placed potentially applicable control alternatives identified and evaluated in the BACT 

analysis into the following three categories: 

 Inherently Lower Emitting Processes/Practices/Designs 

 Add On Controls 

 Combinations of Inherently Lower Emitting Processes/Practices/Designs and Add On 

Controls 

EPA recommends that the BACT analysis should consider potentially applicable control techniques 

from all of the above three categories. 

GHGs under EPA regulations are considered as a single air pollutant, which is the aggregate group of 

the six principal gases, CO2, N2O, CH4, HFCs, PFCs, and SF6. CO2 emissions result from the 

oxidation of carbon in the fuel. CH4 emissions result from incomplete combustion and N2O 

emissions result primarily from low temperature combustion. CO2, N2O, and CH4 are the principal 

GHGs that will be emitted from the PEEC combined cycle unit. 

The combustion of natural gas has the lowest emissions of GHGs of any fossil fuel and emits almost 

30 percent less CO2 than oil, and about 45 percent less CO2 than coal (source: www.naturalgas.org). 

The primary fuel for the PEEC combined cycle unit will be natural gas. ULSD oil will be used as 

backup fuel and will be based on an equivalent of 1,000 hr/yr per CT. It is important to recognize 

that the definition of BACT in 40 CFR 52.21(b)(12) includes use of “clean fuels” as a pollution 

control technique. The EPA PSD and the Title V Permitting Guidance for GHGs states that clean 

fuels which would reduce GHG emissions should be considered while recognizing at the same time 
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that the BACT analysis does not need to include a clean fuel option that would fundamentally 

redefine the source. Therefore, the proposed CTs will be fired with “clean fuels” as included in the 

definition for BACT in the CAA Part 169(3). 

EPA recommends that permit applicants and permitting authorities should identify all “available” 

GHG control options that have the potential for practical application to the source under 

consideration. In its PSD and Title V Permitting Guidance for GHGs, EPA emphasizes on two 

mitigation approaches for CO2 – energy efficiency and carbon capture and storage (CCS). 

Emissions of CH4 and N2O from CTs are less than 0.5 percent of the total CO2e GHG emissions. As 

a result, control options for these pollutants are not practicable although an oxidation catalyst system 

can potentially reduce CH4 emissions. 

Energy Efficiency 

Energy efficiency falls under the general category of lower polluting processes/practices. Applying 

technologies, measures and options that are energy efficient translates not only in the reduction of 

emissions of the particular regulated NSR air pollutant undergoing BACT review, but it also may 

achieve collateral reductions of emissions of other pollutants. There are different categories of energy 

efficient improvements: 

 Technologies or processes that maximize the efficiency of the individual 

emissions unit, and

 Options that could reduce emissions by improving the utilization of thermal 

energy and electricity that is generated and used onsite.

When the efficiency of the power generation process is increased, less fuel is burned to produce the 

same amount of electricity. This provides the benefits of lower fuel costs and reduced air pollutant 

emissions (including CO2). Several recent BACT determinations for GHG emissions concluded that 

high efficiency power generation technology is the only available and feasible control technology. 

Efficient power production is technically feasible and is proposed for the PEEC combined cycle unit. 

Carbon Capture and Storage 

Carbon capture and storage (CCS) falls under the category of add on controls, which are air pollution 

control technologies that remove pollutants from a facility’s emissions stream. EPA suggests that 

CCS is an add on pollution control technology that is “available” for large CO2 emitting facilities 
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including fossil fuel-fired power plants and industrial facilities with high purity CO2 streams. As a 

result, EPA suggests that CCS be considered in Step 1 of the BACT analysis. 

CCS is composed of three main components: CO2 capture and/or compression, transport, and storage. 

Carbon Capture – Before CO2 gas can be sequestered, it must be captured as a relatively pure gas, so 

that it can be feasibly stored. Most power plants and other large point sources use air fired 

combustors, a process that exhausts CO2 diluted with nitrogen. Flue gas from natural gas combined 

cycle plants contains only about 4 percent CO2 by volume. For effective carbon sequestration, the 

CO2 in the exhaust gases must be separated and concentrated due to the low percent by volume. 

The most likely options currently identifiable for CO2 separation and capture include: 

 Absorption (chemical and physical),

 Adsorption (physical and chemical),

 Low temperature distillation,

 Gas separation membranes, and

 Mineralization and biomineralization.

Carbon Transport – After the CO2 is captured, it must be transported to a carbon sequestration site. 

Pipelines are the most common method for transporting large quantities of CO2 over long distances. 

Shipping CO2 via pipeline involves compressing gaseous CO2 to a pressure above 1,160 pounds per 

square inch (psi), to increase CO2 density and make it easier and less expensive to transport. A CO2

pipeline would be similar to a high pressure natural gas pipeline and is technically possible. CO2 also 

can be transported as a liquid in seagoing vessels or via tankers on roads or railways. In these 

instances, the CO2 is held in insulated tanks at low temperatures and relatively low pressures. 

Carbon Storage – In a CCS system, CO2 is captured, it is transported, if necessary, and then stored. 

Geologic formations such as depleted oil and gas reservoirs, unmineable coal seams, and underground 

saline formations are potential options for long term storage. Pressurized CO2 is injected into the 

deep geologic formations through drilled wells. Under high pressure, CO2 turns to liquid and can 

move through a formation as a fluid. Once injected, the liquid CO2 tends to be buoyant and will flow 

upward until it encounters a barrier of non porous rock, which can trap the CO2 and prevent further 

upward migration. When CO2 is injected into a coal seam, it is adsorbed onto the coal surfaces, and 

methane gas is released and produced in adjacent wells. There are other mechanisms for CO2
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trapping as well: CO2 molecules can dissolve in brine, react with minerals to form solid carbonates, or 

adsorb in the pores of the porous rock. 

Deep saline formations, which are layers of porous rock saturated with brine present an enormous 

potential for geologic storage of CO2. However, there is not much experience with saline formations 

as that acquired through resource recovery from oil and gas reservoirs and coal seams. There is 

ongoing research focused on storage in organic rich shale, which is a thin horizontal layer of 

sedimentary rock with low vertical permeability and in basalt formations, which are geologic 

formations of solidified lava. Other possible options include liquid storage in deep ocean areas. 

Oxidation Catalyst 

Catalytic oxidation technology, which is primarily designed to reduce CO emissions will also reduce 

CH4 emissions but to a lesser extent. Oxidation catalysts operate at elevated temperatures where 

excess O2 in the exhaust reacts with CH4 to form CO2. No chemical reagent is necessary. The 

surface of an oxidation catalyst is typically a precious metal. 

Oxidation catalysts are susceptible to fine particles suspended in the exhaust gases that can foul and 

poison the catalyst. Catalyst poisoning reduces catalyst activity and pollutant removal efficiencies. 

The most effective oxidation of CO and VOC emissions is achieved if the catalyst bed is located prior 

to the HRSG in the high temperature region of the CT exhaust. 

Step 2 – Identification of Technically Feasible Control Alternatives 

Under the second step of the top down BACT analysis, a potentially applicable control technique 

listed in Step 1 may be eliminated from further consideration if it is not technically feasible for the 

specific source under review. EPA considers a technology to be potentially applicable if it has been 

demonstrated in practice or is available. 

Energy Efficiency 

Efficient power generation is technically feasible and is being proposed for the PEEC combined cycle 

unit. This is discussed in detail in Step 4. 

Carbon Capture and Storage (CCS) 

In its PSD and Title V permitting guidance for GHGs, EPA states that it does not believe CCS will be 

a technically feasible BACT option in certain cases at this time. To establish that an option is 
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technically feasible, the permitting record should show either that an available control option has been 

demonstrated in practice or is available and applicable, with the term “applicable” generally meaning 

a technology can reasonably be installed and operated on the source type under consideration. EPA 

recognizes the significant logistical hurdles that the installation and operation of a CCS system 

presents and that set it apart from other add on controls that are typically used to reduce emissions of 

other regulated pollutants. In addition, other add on controls typically have an existing accessible 

infrastructure in place to address waste disposal and other offsite needs. It should also be noted that 

while CCS may be available according to EPA, it is not “commercially available”. All current CCS 

projects for power plants are primarily in the demonstration stage. 

Logistical hurdles for CCS may include obtaining contracts for offsite land acquisition (including the 

availability of land), the need for funding (including, for example, government subsidies), timing of 

available transportation infrastructure, developing a site for secure long term storage and 

environmental permitting for underground GHG sequestration. Not every source has the resources to 

overcome the offsite logistical barriers necessary to apply CCS technology to its operations. 

There are no CCS systems commercially available for full scale power plants in the United States. 

On February 3, 2010, President Obama established an Interagency Task Force on Carbon Capture and 

Storage, composed of 14 Executive Departments and Federal Agencies. The Task Force delivered 

several recommendations to the President on August 12, 2010. The Task Force, co-chaired by the 

U.S. Department of Energy (DOE) and the EPA, recommended a comprehensive and coordinated 

strategy to overcome the barriers to the widespread, cost effective deployment of carbon capture and 

storage (CCS) within 10 years, with a goal of bringing five to ten commercial demonstration projects 

online by 2016. These projects, to be deployed with the help of federal funding, are intended to 

demonstrate a range of current generation CCS technologies applied to coal-fired power plants and 

industrial facilities. The Task Force concluded that such research and development efforts were 

designed to reduce the cost of CCS and facilitate cost effective deployment after 2020. However, 

widespread deployment of CCS will occur only if the technology is commercially available at 

economically competitive prices. Therefore, the application of CCS is very much in the development 

stage and not commercially available. 

In November 2010, EPA published the final rule for Federal requirements of Underground Injection 

Control (UIC) for CO2 Geologic Sequestration (GS) Wells, as authorized by the Safe Drinking Water 

Act (SDWA). The final rule establishes new federal requirements for the underground injection of 
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carbon dioxide for the purpose of long term underground storage, or geologic sequestration, and a 

new well class – Class VI – to ensure the protection of underground sources of drinking water 

(USDWs) from injection related activities. Therefore, authorization must be obtained from FDEP 

under this federally delegated program prior to geologic sequestration. Permitting for a Class VI well 

takes many years as exploratory wells are likely required for CO2 sequestration and including drilling 

deep holes, testing, etc., prior to approval of an injection well. Indeed, the exploratory well process to 

assess the formation can take over 2 years for drilling and testing, and approval of the start of an 

injection well process. 

In addition to the limitations of CCS discussed above, the PEEC Project replaces a nominal 

1,200 MW oil and natural gas fired steam electric plant with an nominal 1,250 MW advanced 

combined cycle unit on the same footprint. There is limited space to provide the needed 

infrastructure for CCS on the existing plant property. In addition, the PEEC project is located within 

the industrialized Port with no additional space for CCS facilities. 

Based on these considerations, it can be reasonably concluded that CCS is not applicable to the PEEC 

Project, and consequently not technically feasible. 

Oxidation Catalyst 

Catalytic oxidation is an available control technology for CH4, although no approval for its use for 

this purpose has occurred. The oxidation catalyst will reduce CH4 with the following reaction: 

 CH4 + 2O2  CO2 + 2H2O 

While CH4 emissions can be reduced using an oxidation catalyst, the amount of CO2e reduced is less 

than 0.05 percent. Moreover, the amount of potential CO2e that could be reduced from the PEEC 

combined cycle unit is 40 times lower than the EPA GHG thresholds. Therefore, the addition of an 

oxidation catalyst to the PEEC project for GHG control is neither practicable nor feasible to reduce 

CH4. 

Step 3 – Rank Remaining Control Technologies 

After the list of all available controls is narrowed down to a list of the technically feasible control 

technologies in Step 2 above, Step 3 of the top down BACT process calls for the remaining control 

technologies to be listed in order of overall control effectiveness for the regulated NSR pollutant 
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under review. The most effective control alternative (i.e., the option that achieves the lowest 

emissions level) should be listed at the top and the remaining technologies ranked in descending order 

of control effectiveness. 

Based on the discussion in Steps 1 and 2, the only technically feasible control option for GHGs is 

energy efficiency. 

Step 4 – Economic, Energy, and Environmental Impacts 

Under Step 4 of the top down BACT analysis, economic, energy, and environmental impacts must be 

evaluated for each option remaining under consideration. 

The “top” control option and in the case of GHG the “top” energy reduction technology should be 

established as BACT unless the applicant demonstrates, and the permitting authority agrees, that the 

energy, environmental, or economic impacts justify a conclusion that the most stringent technology is 

not “achievable” in that case. If the most stringent technology is eliminated in this fashion, then the 

next most stringent alternative is considered, and so on. 

The “top” control option for PEEC is energy efficiency. The PEEC combined cycle unit will be 

operating at the combined cycle mode, which is more energy efficient than any electric technology 

using natural gas as the primary fuel and ULSD oil as a backup fuel. FPL has selected the advanced 

MHI “J” or Siemens “H” CTs. These CTs are more energy efficient when compared to other 

available combustion turbine models. Moreover, these CTs will not have duct firing that is slightly 

less efficient since the heat is added to the HRSG directly. The HRSG is a steam generator with the 

overall energy cycle less efficient than combined cycle. While duct firing is still an efficient electric 

generating process for producing maximum generation, is not proposed for PEEC. Thus the PEEC 

combined cycle unit will be the most efficient available. 

The efficiency of the generation technology in producing electricity and fuel utilized are the most 

important aspects in GHG emissions from electric generation projects. Together, efficiency and fuel 

type dictate the amount of GHG emissions per unit of generation. 

An important measure of the efficiency for an electrical generating facility is the units’ heat rate. 

Heat rate is a measurement of how efficiently a unit uses heat energy. It is expressed as the number of 
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BTUs of heat required to produce a kilowatt-hour of energy based on HHV. A heat rate of 3,413 

Btu/kWh reflects an efficiency of 100 percent from thermal energy to electrical energy. 

The PEEC combined cycle unit’s heat rate and energy efficiency was compared to data obtained from 

the U.S. Energy Information Administration (US EIA). Based on data provided in the Annual Energy 

Review 2010 (see http://www.eia.doe.gov/totalenergy/annual/index.cfm), the approximate heat rate 

for electricity for fossil fueled power plants in the U.S. in 2010 was 9,760 Btu/kWh (35.0 percent 

efficiency). 

Based on US EIA’s 2010 annual review of the electrical power industry, the reported average heat 

rate for natural gas firing was 8,185 Btu/kWh (41.7 percent efficiency) including all types of 

generation (see http://www.eia.gov/electricity/annual/pdf/table5.3.pdf). 

Of the generation types (see http://www.eia.gov/electricity/annual/pdf/table5.4.pdf), the average heat 

rates when firing natural gas are: 

 Steam turbine – 10,249 Btu/kWh (33.3 percent efficiency), 

 Natural gas turbine – 11,590 Btu/kWh (29.5 percent efficiency), 

 Internal combustion – 9,917 Btu/kWh (34.4 percent efficiency), and 

 Combined cycle – 7,619 (44.8 percent efficiency) Btu/kWh. 

Using the heat balance predicted data to estimate the power output of the steam turbine generator, and 

the heat rate and efficiency of PEEC when using natural gas and USLD oil are as follows (new and 

clean, based on manufacturer data): 

 Natural gas firing –6,357 to 6,488 Btu/kWh (53.7 to 52.6 percent efficiency) (Baseload at 

75o

F), and 

 Oil firing – 6.745 to 7,171 Btu/kWh (50.6 to 47.6 percent efficiency) (Baseload at 75o

F) 

The overall new and clean heat rate of PEEC using these heat rates for each fuel and an operating 

scenario of 1,000 hr/yr per CT on oil firing, and 7,760 hr/yr per CT on natural gas firing, is estimated 

to range from 6,449 to 6,518 Btu/kWh (52.9 to 52.4 percent efficiency). These estimated heat rates 

are well below the approximate heat rate for all fossil fueled power plants in the U.S. in 2010 and the 

proposed combined cycle unit is 33 percent more efficient than all U.S. fossil fueled plants. When 

comparing to all type of generation using natural gas, the proposed power block will be 20 percent 

more efficient than all generation using natural gas. 
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The PEEC combined cycle unit will be more efficient than other existing combined cycle plants. This 

is a result of utilizing a the latest CT technology that results in greater efficiency in the CT generated 

power and increased exhaust energy through the HRSG to produce more steam electric generation. 

Together this significantly improves the efficiency over earlier generation combined cycle units. 

PEEC will have a heat rate over 10 percent lower than average existing combined cycle plants as 

indicated from EIA 2009 data. The proposed Project will be designed to produce the maximum 

efficiency for the size of the Project (1,250 MW) including the use of inlet cooling that improves 

efficiency. For example, at an inlet temperature of 95°F, the use of evaporative cooling will decrease 

the heat rate by 1 percent or more and translate to a proportional decrease in GHG emissions for the 

amount of fuel used. 

As part of EPA’s clean energy initiatives, EPA developed the Emissions & Generation Resource 

Integrated Database (eGRID) as a resource tool in assessing GHG emissions. eGrid is a 

comprehensive source of data on the environmental characteristics of almost all electric power 

generated in the United States with data available based on a variety of geographic regions and 

locations. Data is also available on a plant specific basis. Based on the latest available eGrid data the 

following are the emissions of CO2 on a generation basis for generation facilities located in the same 

subregion as the Project: 

 Florida Reliability Coordination Council – 1,225.7 lb CO2/MW-hr for all generation 

(including nuclear), 1,417.3 lb CO2/MW-hr for total combustion, and 

 FPL – 881.6 lb CO2/MW-hr for all generation (including nuclear); 1,121.3 lb CO2/MW-hr for 

total combustion generation. 

For PEEC, the net CO2 emission rate on a generation basis will range from about 740 to 

760 lb CO2/MW-hr over the range of operating temperatures and firing the primary fuel, natural gas. 

When compared to the existing generation facilities in the region and FPL’s system, it can be seen 

that PEEC’s GHG emission rates are lower. Therefore, the GHG emissions are much lower than the 

existing generation on a generation basis and PEEC will displace less efficient generating units 

resulting in overall GHG reduction in FPL’s system. FPL’s analysis indicates that PEEC will reduce 

FPL’s system emissions of CO2 by 22 million tons from 2016 through 2047. 
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Step 5 – Select the BACT 

In Step 5 of the BACT determination process, the most effective control option not eliminated in Step 

4 should be selected as BACT for the pollutant and emissions unit under review and included in the 

permit. 

BACT 

Energy efficiency, the only remaining and feasible control technology, is selected as BACT for the 

GHG emissions from the PEEC Project. Energy efficiency plays a major role in affecting GHG 

emissions and EPA suggests that more emphasis will be given to energy efficiency in GHG BACT 

analysis. As demonstrated in the discussion in Step 4, PEEC meets the requirements of energy 

efficiency under EPA’s GHG BACT guidelines. Moreover, the PEEC Project will be part of FPL 

electric generating system and as the most efficient unit located in a major load center (southeast 

Florida), PEEC will have a high capacity factor and displace generation from less efficient generating 

units. FPL’s system analysis indicates that PEEC will reduce FPL’s system emissions of CO2 by 22 

million tons from 2016 through 2047. 

The CCS option was eliminated in Step 2 as not technically feasible for the Project. Although EPA 

considers CCS as available, it is not commercially available. Indeed, EPA recognizes that at present 

CCS is an expensive technology, largely because of the costs associated with CO2 capture and 

compression. In the Guidance, EPA states that even if not eliminated in Step 2 of the BACT analysis, 

on the basis of the current costs of CCS, CCS is more likely to be eliminated from consideration in 

Step 4 of the BACT analysis, even in some cases where underground storage of the captured CO2

near the power plant is feasible. In the case of PEEC, CCS is not a technically feasible control 

technology based on the Project’s overall purpose (replacing a less efficient power plant of almost 

equal size) and its location (no sufficient space for CCS facilities in an existing developed industrial 

area). 

Moreover, while there is a net increase in GHG emission as a result of a “potential emissions” to 

“baseline actual emission” comparison, the more efficient PEEC Project replaces a less efficient 

existing oil and natural gas-fired steam electric generating plant. Taking into account these factors, 

CCS would not be feasible in any calculation of cost effectiveness. 

FPL proposes an output based GHG BACT limit of 877 lb CO2e/MW-hr on a 12-month rolling 

average that would be applicable to the Project. The BACT limit is based on an annual average 
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turbine inlet temperature 75°F, the range in operating loads, 1,000 hr/yr of ULSD oil operation, a 2 

percent margin for the difference between guaranteed heat rates and actual heat rates (the vendor has 

not yet been selected), and a 5 percent margin for degradation over time. This proposed BACT limit 

is reasonable and appropriate based on recent BACT determinations for similar combined cycle 

projects. First, the PacifiCorp’s Lake Side Block 2 combined cycle project was issued a GHG BACT 

limit of 950 lb/MW-hr by the Utah Department of Environmental Quality (Approval Order DAEAN01130310010-11; May 4, 2011). This BACT GHG limit is about 8 percent and 73 lb CO2e/MWhr higher than that proposed for PEEC. This is a difference of over 400,000 tons CO2e per year for 

the MW-hrs that could be generated by PEEC. Second, the draft PSD Permit for GHG Emissions for 

the Lower Colorado River Authority’s Thomas C. Ferguson Power Plant proposed a GHG BACT 

limit equivalent to 918 lb/MW-hr by the EPA Region VI (PSD-TX-1244-GHG, September 28, 2011). 

This BACT GHG limit is about 5 percent and 41 lb CO2e/MW-hr higher than that proposed for 

PEEC. This difference is also equivalent to over 230,000 tons CO2e per year for the MW-hrs that 

could be generated by PEEC. Based on the BACT analysis and these recent permits, the proposed 

GHG BACT limit of 877 lb CO2e/MW-hr on a 12 month rolling average is appropriate as BACT. 

4.3.2 BACT Analysis for PEEC – Auxiliary Boiler, Emergency Generators, Natural Gas Heater, 

Natural Gas Compressor Station and Diesel Fire Pump Engine

The auxiliary boiler, emergency generators, natural gas heaters, natural gas compressor station and 

diesel fire pump engine are all necessary support facilities for the operation of the PEEC combined 

cycle unit. GHG emissions potential for these sources are less than 2 percent of the combined cycle 

system at the maximum requested operation. The actual GHG emissions from these sources are 

expected to be considerably lower than that requested due to their function. The emergency 

generators and diesel fire pump, that will have operational limits of no more than 100 hr/yr will 

normally only be operated a few hours per month for maintenance checks. The auxiliary boiler is 

used for startup and shutdowns that are not expected to be frequent for the advanced combined cycle 

unit. The natural gas compressor station is necessary to maintain natural gas pressure to the 

combustion turbines, but is not operated continuously at full load to serve this purpose. The natural 

gas fuel heater maintains the temperature of natural gas as needed, but is not required to operate 

continuously at full load to serve this purpose. Taken together the actual GHG emissions of these 

sources are expected to be much less than 1 percent of the combined cycle unit. Due to the negligible 

amount of GHG emissions from these sources compared to the combined cycle system, even 100 

percent control of GHG emissions from these units will not make any meaningful reduction in total 

GHG emissions. Moreover, as discussed above, the PEEC project will reduce GHG emissions in 
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FPL’s system by 22 million tons from 2016 through 2047 for an average reduction of about 

700,000 TPY. This is over an order of magnitude lower than the total requested increase in GHG 

emission from these sources. As a result, a detailed BACT analysis of GHG emissions from these 

minor units will therefore not be practicable given that GHG emissions are not an individual unit 

issue. Rather, the GHG emissions of an entire project like PEEC are the most relevant factor in its 

review. As demonstrated in Section 4.3.1, PEEC will be one of the most energy efficient combined 

cycle plants in the U.S. 

A brief discussion of the BACT steps with respect to GHG emissions from auxiliary boiler, 

emergency generators, natural gas heaters, natural gas compressor station and diesel fire pump engine 

is presented below. 

Step 1 – Identify All Available Control Technologies 

The first step in the top down BACT process is to identify all “available” control options. Available 

control options are those air pollution control technologies or techniques (including lower emitting 

processes and practices) that have the potential for practical application to the emissions unit and the 

regulated pollutant under evaluation. 

The definition of BACT in Title 40, Part 52.21(b)(12) of the Code of Federal Regulations [40 CFR 

52.21(b)(12)] includes use of clean fuels as a pollution control technique. The proposed auxiliary 

boiler, natural gas heater and natural gas compressor station will be fired with only natural gas, which 

is the cleanest GHG emitting fuel compared to other fossil fuels due to its low GHG emissions 

potential when combusted. The emergency generators and diesel fire pump require fuel located onsite 

in order to provide to service during emergency situations. 

In the BACT analysis, GHGs are considered as a single air pollutant, which is the aggregate group of 

the six principal gases, CO2, N2O, CH4, HFCs, PFCs, and SF6. CO2 emissions result from the 

oxidation of carbon in the fuel. CH4 emissions result from incomplete combustion, and N2O 

emissions result primarily from low temperature combustion. CO2, N2O, and CH4 are the principal 

GHGs that will be emitted from the auxiliary boiler, emergency generators, natural gas heaters, 

natural gas compressor station and diesel fire pump engine. Emissions of CH4 and N2O are negligible 

compared to CO2 and specific control options for these pollutants are not practicable. 

EPA recommends that permit applicants and permitting authorities should identify all “available” 

GHG control options that have the potential for practical application to the source under 
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consideration. In its PSD and Title V Permitting Guidance for GHGs, EPA emphasizes on two 

mitigation approaches for CO2 – energy efficiency and carbon capture and storage (CCS). CCS is not 

practical for CO2 emissions from the auxiliary boiler, emergency generators, natural gas heaters, 

natural gas compressor station and diesel fire pump engine due to the small amount of CO2 emissions 

potential from this equipment compared to the combined cycle system. Moreover, these units are not 

operated continuously or at their rated capacities making the addition of control equipment 

problematic. 

Energy Efficiency 

In the GHG BACT guidance, EPA has stressed importance of energy efficiency for combustion 

sources. The auxiliary boiler will be used to provide steam to the steam cycle during the startup 

sequences. A boiler's efficiency is measured by its annual fuel utilization efficiency (AFUE). AFUE 

is the ratio of heat output of the boiler compared to the total energy consumed by the boiler. An 

AFUE of 90 percent means that 90 percent of the energy in the fuel becomes heat and the other 

10 percent is lost in the system. In general, fossil fuel fired boilers have high AFUE rating around 

90 percent. For example, based on data from Cleaver Brooks firetube boilers, the fuel to steam 

efficiencies for boilers are in the 90 percent range for natural gas. 

The natural gas heater may be used to warm up the natural gas flowing through the pipeline before 

feeding into the CTs. The heater supplies heat based on the natural gas conditions. Therefore, the 

amount of fuel used in the heater is regulated to that necessary for the natural gas delivered to the CT. 

Similarly, the natural gas compressors are efficient natural gas turbines connected directly to natural 

gas compressors. These natural gas turbine/compressors are used to maintain the necessary pressure 

for natural gas piped to the CTs associated with combined cycle unit. The amount of compression 

necessary is regulated by matching the needed fuel to the natural gas turbines that produce the 

necessary pressure for the CTs. 

The emergency generators and diesel fire pump are designed to meet the applicable NSPS and 

NESHAP for non-road engines. These units maximize efficiency while meeting the required 

emissions standards. 

Step 2 – Identification of Technically Feasible Control Alternatives 

Under the second step of the top down BACT analysis, a potentially applicable control technique 

listed in Step 1 may be eliminated from further consideration if it is not technically feasible for the 
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specific source under review. EPA considers a technology to be potentially applicable if it has been 

demonstrated in practice or is available. The energy efficiency through the regulation of the amount 

of fuel used is considered to be the only technically feasible CO2 control option for the auxiliary 

boiler, emergency generators, natural gas heaters, natural gas compressor station and diesel fire pump 

engine. 

Step 3 – Rank Remaining Control Technologies 

After the list of all available controls is narrowed down to a list of the technically feasible control 

technologies in Step 2, Step 3 of the top down BACT process calls for the remaining control 

technologies to be listed in order of overall control effectiveness for the regulated New Source 

Review (NSR) pollutant under review. Based on the discussion in Steps 1 and 2, the only technically 

feasible control option for CO2 from the auxiliary boiler, emergency generators, natural gas heater, 

natural gas compressor station and diesel fire pump engine is energy efficiency through the regulation 

of fuel to meet the PEEC requirements. 

Step 4 – Economic, Energy, and Environmental Impacts 

Under Step 4 of the top down BACT analysis, economic, energy, and environmental impacts must be 

evaluated for each option remaining under consideration. 

In the top down BACT analysis, the “top” control option should be established as BACT unless the 

applicant demonstrates, and the permitting authority agrees, that the energy, environmental, or 

economic impacts justify a conclusion that the most stringent technology is not “achievable” in that 

case. If the most stringent technology is eliminated in this fashion, then the next most stringent 

alternative is considered. 

The auxiliary boiler, natural gas heaters, and natural gas compressor station will use natural gas. 

GHG emissions for natural gas firing is 116.9 lb CO2e/MMBtu compared to 163.6 lb CO2/MMBtu for 

distillate fuel oil firing based on Subpart C of 40 CFR Part 98, Mandatory Greenhouse Gas Reporting. 

The emission factors include N2O and CH4 at the equivalent rates. Therefore, firing natural gas will 

generate less GHGs than firing oil. 

Step 5 – Select the BACT 

In Step 5 of the BACT determination process, the most effective control option not eliminated in 

Step 4 should be selected as BACT for the pollutant and emissions unit under review and included in 

the permit. 
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Energy efficiency through the regulation of fuel use to meet the function is the only remaining and 

feasible control technology is selected as BACT for the GHG emissions from the auxiliary boiler, 

emergency generators, natural gas heaters, natural gas compressor station and diesel fire pump 

engine. Additionally, the use of natural gas in the auxiliary boiler, natural gas heater and natural gas 

compressor station results in the lowest GHG emission practicable. 

As mentioned in Step 1, an important measure of the efficiency for a boiler is the units’ AFUE natural 

gas boilers have an AFUE rating around 90 percent in general, which is higher than other fossil fuel 

fired boilers. In addition, all units are operated only to meet the requirements of PEEC combined 

cycle units operation. Thus, fuel use is optimized resulting in lower GHG emissions than if these 

units operate continuously. 

The auxiliary boiler, emergency generators, natural gas heater, natural gas compressor station and 

diesel fire pump engine together accounts for less than 2 percent of the total GHG emissions potential 

of the PEEC Project with expected emissions to be much less than 1 percent. Moreover, these minor 

GHG emission units support the overall Project and, as discussed above, PEEC will be one of the 

most efficient combined cycle units in the U.S. PEEC’s GHG emissions on a lb/MW-hr basis will be 

one of the lowest in the country. The operation of these minor units will be limited: the auxiliary 

boiler will be based on 2,000 hr/yr; emergency generators and fire pump engine are limited to 100 

hours or less; the natural gas heaters are operated as necessary; and only two of three natural gas 

turbine/compressors will normally be operated and only used to regulate natural gas pressure. 

Together, the negligible amount of GHG emissions potential, limitation in operating hours, and use of 

the natural gas fuel, represents the best available option in controlling GHG emissions from these 

emission units. This is consistent with the definition of BACT, which allows “a design, equipment, 

work practice, operational standard, or combination thereof, may be prescribed instead to satisfy the 

requirement for the application of best available control technology.” Due to the negligible amount 

of GHG emissions potential, a numerical GHG emission limit is unnecessary. 
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5.0 AMBIENT MONITORING ANALYSIS 

If PSD review is required, FDEP’s PSD regulations require that an air quality monitoring analysis be 

conducted for each criteria and non-criteria pollutant subject to regulation under the CAA before a 

major stationary source or major modification at a major stationary source is constructed. Criteria 

pollutants are those pollutants for which AAQS have been established. Non-criteria pollutants are 

those pollutants that may be regulated by emission standards, for which AAQS have not been 

established. This analysis may be performed by the use of modeling and/or by monitoring the air 

quality. In addition, if EPA has not established an acceptable ambient monitoring method for the 

pollutant, monitoring is not required. 

For PEEC, the net emissions changes will be less than the PSD SERs, except for GHG. An air 

quality monitoring impact analysis for GHG is not required by NSR under EPA PSD air regulations. 

However, as a supplement to the Air Construction Permit Application, air quality monitoring data for 

other regulated pollutants are provided, which demonstrate that Broward County is in attainment of 

the AAQS for all criteria pollutants. A summary of the maximum pollutant concentrations 

representative of air quality in Broward County from 2008 through 2010 is presented in Table 5-1. 

These data indicate that the maximum air quality concentrations measured in the region are well 

below applicable standards. 

The monitoring data are also used to estimate background concentrations that are added to the 

maximum concentrations predicted for the existing Units 1 through 4 and PEEC to provide total air 

quality impacts that can be compared to the AAQS (see Section 6.1). 
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6.0 AIR QUALITY IMPACT ANALYSIS 

PEEC will significantly improve air quality in the vicinity of the facility. PEEC will reduce 

emissions of air pollutants, except for GHG, by approximately 14,000 TPY compared to recent Plant 

operation, or an emission reduction of approximately 88 percent. PEEC will reduce GHG emissions 

in FPL’s system by an average of 700,000 TPY. 

For the PEEC Project, the net emissions changes will be less than the PSD SERs. As a result, an air 

quality impact analysis is not required by NSR under FDEP air regulations. However, as a 

supplement to the Air Construction Permit Application, air quality impacts were estimated for the 

existing Plant and PEEC in the vicinity of the facility for comparison to the AAQS. The general 

modeling approach followed EPA and FDEP modeling guidelines. 

As shown in Table 6-1, the maximum total air quality impacts for PEEC and the existing Port 

Everglades Plant are predicted to be below and in compliance with the AAQS. Total air quality 

impacts include the maximum impacts predicted for the PEEC units, added to appropriate background 

concentrations. Background concentrations are based on the maximum measured concentration from 

representative air quality data in the vicinity of the facility. 

For SO2, the predicted maximum impacts for PEEC alone will be less than 5 percent of the AAQS 

and, with background sources, the total predicted maximum impacts are less than 60 percent of the 

AAQS. The maximum total air quality impacts are primarily due to background concentrations, 

particularly for the 1 hour average impacts. 

For PM10, the predicted maximum impacts for PEEC alone will be less than 5 of the AAQS and, with 

background sources, less than 40 percent of the AAQS. Similar to SO2, the maximum total air quality 

impacts are primarily due to background concentrations. 

For NO2 and CO, the predicted maximum total air quality impacts are also primarily due to 

background concentrations. For PEEC alone, the predicted maximum NO2 and CO impacts are about 

16 and 1 percent, respectively, of the AAQS. The predicted maximum total NO2 and CO impacts for 

PEEC with background sources are about 65 and 23 percent of the AAQS. 

The following sections present a summary of the air quality modeling methodology for the air quality 

impact analyses for the Project. 
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6.1 Air Modeling Analysis Approach 

6.1.1 Air Modeling Scenarios

Air quality analyses were performed to assess the maximum impacts for the existing Port Everglades 

Plant and PEEC. For the existing Plant, air quality impacts were predicted for the existing Units 1 

through 4, which were added to non-modeled background concentrations (see Subsection 6.1.8) to 

produce total air quality impacts. These impacts were then compared to the AAQS for SO2, NO2, 

PM10, PM2.5, and CO. 

Similarly, PEEC air quality impacts were predicted for each of the CT vendors and other air emission 

units for PEEC, such as the fuel heater, natural gas compressor station, and auxiliary boiler, to 

produce total air quality impacts, which were then compared to the AAQS for SO2, NO2, PM10, PM2.5, 

and CO. 

6.1.2 General Modeling Approach

In general, when model predictions are used to determine compliance with AAQS, current policies 

stipulate that the highest annual and the HSH short term (i.e., 24 hours or less) concentrations are 

compared to the applicable AAQS when using 5 years of meteorological data for the analysis. The 

HSH concentration is calculated each year for a receptor field by: 

1. Eliminating the highest concentration predicted at each receptor, 

2. Identifying the second highest concentration at each receptor, and 

3. Selecting the highest concentration among these second highest 

concentrations. 

The HSH approach is consistent with AAQS, which generally allows a short term average 

concentration to be exceeded once per year at each receptor. 

For the 1-hour NO2 impact, the 5-year averages of the 98th (8th highest) percentile of the daily 

maximum 1-hour average concentrations at each receptor were determined. The maximum 5-year 

average of these values is used to estimate the maximum impact. Similarly, for the 1-hour SO2

impact, the 5-year averages of the 99th (4th highest) percentile of the daily maximum 1-hour average 

concentrations at each receptor were determined. The maximum 5-year average of these values is 

used to estimate the maximum impact. 
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The AAQS analysis performed for the Project is a source analysis that evaluates whether the 

concentrations from sources will comply with the AAQS. These concentrations include the modeled 

impacts from sources at the facility added to a background concentration. The background 

concentration accounts for sources not included in the modeling analysis. 

6.1.3 Model Selection

The selection of air quality models to calculate air quality impacts for the existing Port Everglades 

Plant and PEEC must be based on the models’ ability to simulate impacts in the vicinity of the 

facility. The American Meteorological Society and EPA Regulatory Model (AERMOD) dispersion 

model was used to evaluate the pollutant impacts due to the proposed sources at PEEC. AERMOD 

(Version 11103) is available on the EPA’s Internet web site, Support Center for Regulatory Air 

Models (SCRAM), within the Technology Transfer Network (TTN). A listing of AERMOD model 

features is presented in Table 6-2. 

The EPA and FDEP recommend that AERMOD be used to predict pollutant concentrations at 

receptors located within 50 km of a source. AERMOD calculates hourly concentrations based on 

hourly meteorological data. AERMOD is applicable for the type of Project sources and area in which 

the Project is located since it is recognized as containing the latest scientific algorithms for simulating 

plume behavior in all types of terrain. 

AERMOD was used to predict the maximum pollutant concentrations due to the existing Port 

Everglades Plant and PEEC in nearby areas surrounding the facility. 

For modeling analyses that will undergo regulatory review, such as determining compliance with 

AAQS, the following model features are recommended by EPA for rural mode and are referred to as 

the regulatory default options in AERMOD: 

1. Final plume rise at all receptor locations, 

2. Stack tip downwash, 

3. Buoyancy induced dispersion, 

4. Default wind speed profile coefficients for rural mode, 

5. Default vertical potential temperature gradients, and 

6. Calm wind processing. 

The EPA regulatory default options were used to address maximum impacts. 
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6.1.4 Meteorological Data

Meteorological data used in AERMOD to determine air quality impacts consisted of a concurrent 

5 year period of hourly surface weather observations and upper air sounding data collected from the 

National Weather Service (NWS) stations located at the Fort Lauderdale-Hollywood International 

Airport and Florida International University (FIU) in Miami, respectively. The 5 year period of the 

meteorological data was from 2006 through 2010 and was prepared by the FDEP. The NWS office at 

the airport is located approximately 2.5 km (1.2 miles) southwest of PEEC. The areas between the 

airport and PEEC are flat with very similar land characteristics. As such, the meteorological 

parameters collected at Fort Lauderdale-Hollywood International Airport are considered to be very 

representative of those that exist at PEEC. 

Since the airport meteorological station is only 2.5 km from PEEC and the terrain between the two 

sites is flat, the wind direction and wind speed frequencies that are experienced at the airport are 

considered to be very similar to that experienced at PEEC. As such, the airport wind direction and 

wind speed frequencies are considered to be representative for PEEC. 

6.1.5 Emission Inventory

Existing FPL Units – The emissions and stack parameters for the existing Units 1 through 4 are 

presented in Table 6-3. Units 1 through 4 will be retired before PEEC begins operation. 

The short term emission rates were based on the maximum rate allowed by the permit for each 

unit (Permit No. 0110036-009-AV, February 2010), EPA AP-42 emission factors for combustion of 

fuel oil, or, in the case of SO2, the maximum historical sulfur content of 1 percent used over the last 

5 years (equivalent to about 1.1 lb/MMBtu). 

PEEC Sources – Summaries of the criteria pollutant emission rates, physical stack and stack 

operating parameters for the combined cycle units for PEEC that were used in the air modeling 

analysis are presented in Tables 2-1A to 2-2A for the MPS ”J” CTs for natural gas firing and fuel oil 

firing, respectively. Similarly, summaries are presented in Tables 2-1B to 2-2B for the Siemens “H” 

CTs for natural gas firing and fuel oil firing, respectively. 

The maximum air quality impacts for PEEC were predicted for a range of possible operating 

conditions. The emission and stack operating parameters are presented for three operating loads and 

35F, 75F, and 95F ambient temperatures for the CTs firing both natural gas and oil. 
January 2012 6-5 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

A total of 18 modeling scenarios were considered for the MPS ”J” CTs operating in the following 

conditions for natural gas and oil: 

 Ambient temperatures of 35F, 75F, and 95°F at: 

– 100 percent operating load 

– 75 percent operating load 

- 50 percent operating load 

A total of 18 modeling scenarios were also considered for the Siemens “H” CTs operating in the 

following conditions: 

 For natural gas firing, ambient temperatures of 35F, 75F, and 95°F at: 

– 100 percent operating load 

– 80 percent operating load 

- 60 percent operating load 

 For fuel oil firing, ambient temperatures of 35F, 75F, and 95°F at: 

– 100 percent operating load 

– 80 percent operating load 

- 70 percent operating load 

The load analysis was performed using the exit gas operating data for the MPS “J” CT and the 

Siemens “H” CT. Once the worst case operating condition was determined for each CT, subsequent 

analyses were performed with exit gas operating data specific to each CT vendor. 

The proposed combined cycle unit will have HRSG stack heights of 149 ft. Because the proposed 

stack heights are less than GEP, building downwash effects were included in the modeling analysis. 

In addition, since the stack heights for the other PEEC sources are also less than GEP, building 

downwash effects were included in the modeling analysis for these sources. 

A separate air quality analysis was performed for the auxiliary boiler alone, which will be used to 

assist in startup for one of the CTs. As discussed previously, the combustor for the CTs requires 

steam for combustor cooling, which normally comes from the HRSG. For startup, an auxiliary boiler 

is required to supply steam for the combustion process for only one CT. Once sufficient quality and 

quantity of steam is available from the HRSG, steam from the auxiliary boiler is not required for the 

other CTs. It was conservatively assumed that the annual operation of the auxiliary boiler would be 

2,000 hr/yr for the startup of the CT. 
January 2012 6-6 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

Additional analyses were performed for SO2, NOx, PM10, PM2.5, and CO emissions to address the 

combined impact of the CTs and other PEEC sources. Detailed descriptions of the other PEEC 

sources are presented in Tables 2-3 through 2-8 in Section 2.0. 

The proposed CTs will have a HRSG stack height of 149 ft and an inner stack diameter of 22 ft. 

Because the proposed stack heights are less than GEP, building downwash effects were included in 

the modeling analysis (see following section on building downwash). In addition, since the stack 

heights for the other PEEC sources are also less than GEP, building downwash effects were included 

in the modeling analysis for these sources. 

6.1.6 Building Downwash Effects

All significant structures for PEEC were identified by the plot plan (see Figure 2-1). The following 

structures were processed in the EPA Building Profile Input Program [(BPIP), Version 04274] to 

determine direction specific structure heights and widths for each 10 degree azimuth direction for 

each source that was included in the modeling analysis: 

Structure Height (ft) Width (ft) Length (ft) 

 

 CT Air Inlet 98 24 58 

 HRSG Structure 78 42 102 

 CT Structure 35 24 99 

 Compressor Station 

 

10.5 

 

7 20 

As a conservative estimate of potential impacts, the natural gas compressors were assumed to be in an 

enclosed structure. However, each of the natural gas compressors may stand alone and not be 

enclosed in any structure. 

Based on this evaluation, the GEP stack height for the CTs was determined to be 193 ft. Therefore, 

building downwash effects for the CTs were included in the air modeling analyses. With stack 

heights of 60 ft or less for the other PEEC sources, building downwash effects were included in the 

modeling analysis for these sources. The BPIP files are presented in Appendix D. 
January 2012 6-7 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

6.1.7 Receptor Locations

To determine the maximum impact for all pollutants and averaging times in the vicinity of PEEC, 

concentrations were predicted at receptors located in detailed receptor grids centered on the proposed 

combined cycle unit, the modeling origin, and extended from the property boundary out to 5 km. 

More than 3,000 receptors were used in the analysis to determine the maximum impacts for the 

existing Units 1 through 4 and PEEC. Although the terrain around the immediate vicinity is flat, 

receptor elevations were included at each receptor in the analysis. 

Along the property boundary, a Cartesian receptor grid was used to predict concentrations at 75 

receptors spaced at 50 meter intervals. In addition, a general Cartesian grid was used to predict 

concentrations beyond the property boundary out to 5 km. Receptors were located at the following 

intervals and distances from the origin: 

 Along the property boundary or fenceline – 50 meters, 

 Beyond the fenceline to 2 km – 100 meters, and 

 From 2 km to 5 km – 250 meters. 

The receptors used in the analysis to determine the maximum impacts for the existing Port Everglades 

Plant and PEEC are presented in Appendix D. 

Impacts were also predicted at the PSD Class I area of the Everglades NP using an array of 901 

discrete receptors and elevations covering the entire NP that were obtained from the National Park 

Service Class I extraction program. The receptors were converted to Universal Transverse Mercator 

(UTM) coordinates, North American Datum 83 (NAD83). 

6.1.8 Background Concentrations

Background concentrations are necessary to determine total ambient air quality impacts to 

demonstrate compliance with the AAQS. “Background concentrations” are defined as concentrations 

due to sources other than those specifically included in the modeling analysis. For all pollutants, 

background would include other point sources not included in the modeling, fugitive emission 

sources, and natural background sources. In general, monitoring data collected near the area in which 

the air quality impact is performed is used for this purpose. 
January 2012 6-8 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

Summaries of ambient SO2, PM10, PM2.5, NO2, and CO concentrations measured are presented in 

Section 5.0. Based on data collected from 2008 to 2010, the highest annual and 3 year average of 

second highest short term concentrations were selected to represent background concentrations and 

are as follows: 

 Background 

Concentration 

Pollutant Averaging Period (ppm) (μg/m3) 

SO2 1-hour 0.038 99.6 

 3-hour 0.036 93.0 

 24-hour 0.008 20.9 

 Annual 0.0010 2.6 

 

PM10 24-hour NA 18.1 

 Annual NA 49 

 

PM2.5 24-hour NA 7.1 

 Annual NA 16 

 

NO2 1-hour 0.049 92.2 

 Annual 0.0096 11.9 

 

CO 1-hour 2.8 3,182 

 8-hour 2.0 2,300 

6.2 Model Results 

6.2.1 Air Quality Impacts for the Existing Units 1 through 4

Air modeling analyses were performed to determine the maximum total air quality impacts of SO2, 

NO2, PM10, PM2.5, and CO from the existing Units 1 through 4 added to background concentrations. 

A summary of the maximum total air quality predicted for comparison to the AAQS in the Plant’s 

vicinity is presented in Table 6-4. These results indicate that the maximum pollutant impacts 

predicted for the existing Units 1 through 4 are less than the AAQS. 

The highest annual, HSH 24 hour, and HSH 3 hour SO2 concentrations are predicted to be 32, 221, 

and 604 micrograms per cubic meter (μg/m3

), respectively. These concentrations are below the 

annual, 24 hour, and 3 hour SO2 AAQS of 60, 260, and 1,300 μg/m3

, respectively. 

The highest annual NO2 concentration is predicted to be 21μg/m3

, which is below the annual NOx

AAQS of 100 μg/m3

. 
January 2012 6-9 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

The highest annual and HSH 24 hour PM10 concentrations are 19 and 56 μg/m3, respectively. These 

concentrations are below the annual and 24 hour PM10 AAQS of 50 and 150 μg/m3

, respectively. 

The highest annual and 24 hour PM2.5 concentrations are 8 and 21 μg/m3

, respectively. These 

concentrations are below the annual and 24 hour PM2.5 AAQS of 15 and 35 μg/m3

, respectively. 

The HSH 8 hour and HSH 1 hour CO concentrations are predicted to be 2,314 and 3,203 μg/m3

, 

respectively. These concentrations are below the 8 hour and 1 hour CO AAQS of 10,000 and 40,000 

μg/m3

, respectively. It should be noted that the background concentrations contribute more than 99 

percent to the total air quality impacts. 

6.2.2 Air Quality Impacts due to PEEC

The maximum pollutant concentrations predicted for PEEC for the CTs firing natural gas and fuel oil 

are given in Table 6-5 for impacts in the Plant’s vicinity. Based on the worst-case operating 

condition, two additional modeling analyses were performed. The first analysis included the CTs and 

fuel heater and the second analysis included the CTs, fuel heater, and natural gas compressor station. 

The results of these additional analyses are also presented in Table 6-5. 

The maximum concentrations for PEEC, including the CTs, fuel heater, and gas compression station 

as well as background concentrations, for comparison to the AAQS are presented in Table 6-6 for 

impacts in the Plant’s vicinity. As shown in these tables, the modeling results indicate that maximum 

concentrations are predicted to be less than the AAQS and are comparable among the CT vendors 

considered. 

CTs and Fuel Heater 

For the CTs and fuel heater, the highest annual, 24 hour, 3 hour, and 1 hour SO2 concentrations are 

predicted to be 3, 24, 98, and 106 μg/m3

, respectively. These concentrations are below the annual, 24 

hour, 3 hour, and 1 hour SO2 AAQS of 60, 260, 1,300, and 197 μg/m3

, respectively. 

The highest annual and 1 hour NO2 concentrations are predicted to be 13 and 120 μg/m3

, respectively, 

which are below the annual and 1 hour NO2 AAQS of 100 and 188 μg/m3

, respectively. 

The highest annual and 24 hour PM10 concentrations are 19 and 54 μg/m3

, respectively. These 

concentrations are below the annual and 24 hour PM10 AAQS of 50 and 150 μg/m3

, respectively. 
January 2012 6-10 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

The highest annual and 24 hour PM2.5 concentrations are 8 and 21 μg/m3, respectively. These 

concentrations are below the annual and 24 hour PM2.5 AAQS of 15 and 35 μg/m3

, respectively. 

The highest 8 hour and 1 hour CO concentrations are predicted to be 2,333 and 3,219 μg/m3

, 

respectively. These concentrations are below the 8 hour and 1 hour CO AAQS of 10,000 and 

40,000 μg/m3

, respectively. Similar to the air quality impacts predicted for the existing FPL units, the 

background concentrations contribute more than 99 percent to the total air quality impacts. 

CTs, Fuel Heater, and Natural Gas Compressor Station 

For the CTs, fuel heater, and natural gas compressor station, the results are similar to or slightly 

higher than those for the CTs and fuel heater alone. For the CTs and fuel heater, the highest annual, 

24 hour, 3 hour, and 1 hour SO2 concentrations are predicted to be 3, 24, 99, and 106 μg/m3

, 

respectively. These concentrations are below the annual, 24 hour, 3 hour, and 1 hour SO2 AAQS of 

60, 260, 1,300, and 197 μg/m3

, respectively. 

The highest annual and 1 hour NO2 concentrations are predicted to be 13 and 123 μg/m3

, respectively, 

which are below the annual and 1 hour NO2 AAQS of 100 and 188 μg/m3

, respectively. 

The highest annual and 24 hour PM10 concentrations are 19 and 54 μg/m3

, respectively. These 

concentrations are below the annual and 24 hour PM10 AAQS of 50 and 150 μg/m3

, respectively. 

The highest annual and 24 hour PM2.5 concentrations are 8 and 21 μg/m3

, respectively. These 

concentrations are below the annual and 24 hour PM2.5 AAQS of 15 and 35 μg/m3

, respectively. 

The highest 8 hour and 1 hour CO concentrations are predicted to be 2,334 and 3,220 μg/m3

, 

respectively. These concentrations are below the 8 hour and 1 hour CO AAQS of 10,000 and 

40,000 μg/m3

, respectively. Again, the background concentrations contribute more than 99 percent to 

the total air quality impacts. 

Auxiliary Boiler 

The maximum concentrations for the auxiliary boiler for PEEC with background concentrations for 

comparison to the AAQS are presented in Table 6-7. It should be noted that the auxiliary boiler is 

needed only for the MPS “J” CTs for startup of the CT. As shown in Table 6-7, the modeling results 

indicate that maximum concentrations due to the auxiliary boiler are also predicted to be less than the 

AAQS and are similar to those predicted for the CTs and other PEEC sources. 
January 2012 6-11 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

The highest annual, 24 hour, 3 hour, and 1 hour SO2 concentrations are predicted to be 2.6, 22, 96, 

and 104 μg/m3

, respectively. These concentrations are below the annual, 24 hour, 3 hour, and 1 hour 

SO2 AAQS of 60, 260, 1,300, and 197 μg/m3

, respectively. 

The highest annual and 1 hour NO2 concentrations are predicted to be 12 and 120 μg/m3

, which are 

below the annual NOx AAQS of 100 and 188 μg/m3

, respectively. 

The highest annual and 24 hour PM10 concentrations are 18 and 51 μg/m3

, respectively. These 

concentrations are below the annual and 24 hour PM10 AAQS of 50 and 150 μg/m3

, respectively. 

The highest 8 hour and 1 hour CO concentrations are predicted to be 2,329 and 3,238 μg/m3

, 

respectively. These concentrations are below the 8 hour and 1 hour CO AAQS of 10,000 and 40,000 

μg/m3

, respectively. 

Examples of the modeling input and summary files are provided in Appendix E. 

6.2.3 Air Quality Impacts Predicted at the Everglades NP

Air quality impacts for Units 1 through 4 at the existing Port Everglades Plant and PEEC were also 

predicted for SO2, NO2, PM10, and PM2.5 at the PSD Class I area of the Everglades NP. A summary 

of these maximum predicted impacts is presented in Table 6-8. These results indicate that the 

maximum pollutant impacts predicted for PEEC are much lower than those for existing Units 1 

through 4. 

6.3 Conclusions 

Based on these air quality modeling analyses, the maximum pollutant concentrations due to PEEC are 

predicted to be less than the AAQS and will comply with all applicable AAQS. Indeed, the modeling 

results clearly demonstrate that Florida’s air quality will be protected and be substantially improved 

with PEEC. This is demonstrated by Figure 6-1, which presents the maximum total air quality 

impacts predicted for the existing Units 1 through 4 and PEEC compared to the AAQS. As shown in 

Figure 6-1, there is improvement in the maximum total air quality concentrations for SO2 and PM10

with PEEC. 
January 2012 6-12 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

In conclusion, PEEC will reduce actual emissions of air pollutants by more than 14,000 TPY from the 

existing operation, or more than approximately 90 percent reduction, while improving the general air 

quality in the vicinity of PEEC. 
 January 2012 REF-1 113-87618 

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

REFERENCES 

Huber, A.H. and W.H. Snyder, 1976. Building Wake Effects on Short Stack Effluents. Preprint 

Volume for the Third Symposium on Atmospheric Diffusion and Air Quality, American 

Meteorological Society, Boston, Massachusetts. 

U.S. Environmental Protection Agency. 1978. Guidelines for Determining Best Available Control 

Technology (BACT). Office of Air Quality Planning and Standards. 

U.S. Environmental Protection Agency (EPA). 1982. Air Quality Criteria for Particulate Matter and 

Sulfur Oxides. Vol. 3. 

U.S. Environmental Protection Agency. 1987. Ambient Monitoring Guidelines for Prevention of 

Significant Deterioration. EPA Report No. EPA 450/4-87-007. 

U.S. Environmental Protection Agency. 1990. Prevention of Significant Deterioration Workshop 

Manual. 

U.S. Environmental Protection Agency. 1990. “Top-Down” Best Available Control Technology 

Guidance Document (Draft). Research Triangle Park, North Carolina. 

U.S. Environmental Protection Agency. 1993. “Alternative Control Techniques Document—NOx

Emissions from Stationary Gas Turbines”. Pages 6-20. 

U.S. Environmental Protection Agency. 2011. User's Guide for the AMS/EPA Regulatory ModelAERMOD. Through Addendum, December 2011. 

U.S. Environmental Protection Agency. 2009. Guideline on Air Quality Models. Appendix W, 

40 CFR 52. 
TABLES 

 
January 2012 113-87618

Parameter Units 35 °F 59 °F 75 °F 95 °F 

CT/HRSG Stack Data

Height ft 149 149 149 149

Diameter ft 22.0 22.0 22.0 22.0

100 Percent Load

 Temperature o

F 196 195 195 195

 Velocity ft/sec 61.1 58.9 57.3 55.3

Maximum Hourly Emissions per CT

 SO2 lb/hr 17.0 16.3 15.8 15.2

 PM/PM10/PM2.5 lb/hr 8.4 8.1 7.8 7.5

 NOx lb/hr 21.4 20.5 19.8 19.0

 CO lb/hr 58.5 56.2 54.3 52.1

 VOC (as methane) lb/hr 3.7 3.6 3.5 3.3

 Sulfuric Acid Mist lb/hr 3.3 3.2 3.1 3.0

75 Percent Load

 Temperature o

F 184 185 186 187

 Velocity ft/sec 49.2 47.2 45.8 44.2

Maximum Hourly Emissions per CT

 SO2 lb/hr 13.7 13.0 12.6 12.0

 PM/PM10/PM2.5 lb/hr 6.8 6.5 6.3 6.0

 NOx lb/hr 17.0 16.1 15.5 14.8

 CO lb/hr 46.6 44.2 42.4 40.6

 VOC (as methane) lb/hr 3.0 2.8 2.7 2.6

 Sulfuric Acid Mist lb/hr 2.67 2.53 2.44 2.34

50 Percent Load

 Temperature o

F 184 185 186 187

 Velocity ft/sec 38.7 38.0 37.4 36.7

Maximum Hourly Emissions per CT

 SO2 lb/hr 10.4 9.9 9.6 9.2

 PM/PM10/PM2.5 lb/hr 5.3 5.1 4.9 4.8

 NOx lb/hr 13.0 12.3 11.8 11.4

 CO lb/hr 35.5 33.7 32.4 31.1

 VOC (as methane) lb/hr 2.3 2.1 2.1 2.0

 Sulfuric Acid Mist lb/hr 2.03 1.93 1.87 1.79

a

 Refer to Appendix A for detailed information on basis of pollutant emission rates and operating data. 

Sources: MPS, 2011; Golder, 2011.

Operating and Emission Data a

 for Ambient Temperature 

STACK, OPERATING, AND EMISSION DATA

TABLE 2-1A

Combustion Turbine/ HRSG

FOR THE COMBUSTION TURBINES/HRSGS - 

 NATURAL GAS COMBUSTION, MPS 501J CT

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxtab2-1A
January 2012 113-87618

Parameter Units 35 °F 59 °F 75 °F 95 °F 

CT/HRSG Stack Data

Height ft 149 149 149 149

Diameter ft 22.0 22.0 22.0 22.0

100 Percent Load

 Temperature o

F 196 195 195 195

 Velocity ft/sec 63.1 60.4 58.2 55.9

Maximum Hourly Emissions per CT

 SO2 lb/hr 15.6 14.9 14.3 13.7

 PM/PM10/PM2.5 lb/hr 15.1 13.9 13.7 12.6

 NOx lb/hr 21.2 20.2 19.4 18.6

 CO lb/hr 32.2 31.0 30.0 28.0

 VOC (as methane) lb/hr 3.7 3.5 3.4 3.2

 Sulfuric Acid Mist lb/hr 3.0 2.9 2.8 2.7

80 Percent Load

 Temperature o

F 184 185 186 187

 Velocity ft/sec 51.1 48.6 47.8 46.2

Maximum Hourly Emissions per CT

 SO2 lb/hr 12.9 12.0 11.6 10.9

 PM/PM10/PM2.5 lb/hr 12.4 11.2 11.0 10.9

 NOx lb/hr 17.6 16.4 15.8 14.9

 CO lb/hr 54.0 50.0 48.0 45.0

 VOC (as methane) lb/hr 3.1 2.9 2.8 2.6

 Sulfuric Acid Mist lb/hr 2.51 2.34 2.26 2.13

60 Percent Load

 Temperature o

F 184 185 186 187

 Velocity ft/sec 43.2 41.6 41.1 40.0

Maximum Hourly Emissions per CT

 SO2 lb/hr 10.5 9.9 9.5 9.0

 PM/PM10/PM2.5 lb/hr 10.7 10.6 10.5 10.4

 NOx lb/hr 14.4 13.5 13.0 12.2

 CO lb/hr 44.0 41.1 40.0 37.2

 VOC (as methane) lb/hr 2.5 2.4 2.3 2.1

 Sulfuric Acid Mist lb/hr 2.03 1.92 1.85 1.75

a

 Refer to Appendix B for detailed information on basis of pollutant emission rates and operating data. 

Sources: Siemens, 2011; Golder, 2011.

Operating and Emission Data a

 for Ambient Temperature 

STACK, OPERATING, AND EMISSION DATA

TABLE 2-1B

Combustion Turbine/ HRSG

FOR THE COMBUSTION TURBINES/HRSGS - 

NATURAL GAS COMBUSTION, SIEMENS H CT

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:tab2-1B
January 2012 113-87618

Parameter Units 35 °F 59 °F 75 °F 95 °F 

CT/HRSG Stack Data

Height ft 149 149 149 149

Diameter ft 22 22 22 22

100 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 77.1 73.3 70.9 68.0

Maximum Hourly Emissions per CT

 SO2 lb/hr 4.0 3.7 3.6 3.4

 PM/PM10/PM2.5 lb/hr 20.8 19.8 19.2 18.4

 NOx lb/hr 78.2 73.3 70.6 66.8

 CO lb/hr 208.3 195.3 187.9 177.9

 VOC (as methane) lb/hr 34.0 31.9 30.7 29.0

 Lead lb/hr 0.773 0.727 0.699 0.665

 Sulfuric Acid Mist lb/hr 0.04 0.03 0.03 0.03

75 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 62.9 60.0 58.1 55.5

Maximum Hourly Emissions per CT

 SO2 lb/hr 3.2 3.1 2.9 2.8

 PM/PM10/PM2.5 lb/hr 17.0 16.3 15.7 15.1

 NOx lb/hr 63.4 60.0 57.7 54.8

 CO lb/hr 168.9 159.7 153.7 145.9

 VOC (as methane) lb/hr 27.6 26.1 25.1 23.8

 Lead lb/hr 0.630 0.596 0.573 0.547

 Sulfuric Acid Mist lb/hr 0.03 0.03 0.03 0.03

60 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 53.7 51.5 49.9 47.8

Maximum Hourly Emissions per CT

 SO2 lb/hr 2.8 2.7 2.6 2.5

 PM/PM10/PM2.5 lb/hr 14.5 13.9 13.5 13.0

 NOx lb/hr 55.0 52.1 50.3 47.9

 CO lb/hr 146.4 138.8 134.0 127.5

 VOC (as methane) lb/hr 23.9 22.7 21.9 20.8

 Lead lb/hr 0.547 0.518 0.500 0.478

 Sulfuric Acid Mist lb/hr 0.03 0.02 0.02 0.02

a

 Refer to Appendix A for detailed information on basis of pollutant emission rates and operating data. 

Sources: MPS, 2011; Golder, 2011.

Combustion Turbine/ HRSG

STACK, OPERATING, AND EMISSION DATA

TABLE 2-2A

Operating and Emission Data a

 for Ambient Temperature 

FOR THE COMBUSTION TURBINES/HRSGS - 

ULTRA LOW-SULFUR DISTILLATE OIL COMBUSTION, MPS 501J CT

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxtab2-2A
January 2012 113-87618

Parameter Units 35 °F 59 °F 75 °F 95 °F 

CT/HRSG Stack Data

Height ft 149 149 149 149

Diameter ft 22 22 22 22

100 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 79.4 75.8 72.8 68.3

Maximum Hourly Emissions per CT

 SO2 lb/hr 4.1 3.9 3.8 3.6

 PM/PM10/PM2.5 lb/hr 60.1 57.0 55.0 51.9

 NOx lb/hr 88.8 84.6 81.0 77.3

 CO lb/hr 68.0 64.0 62.0 59.0

 VOC (as methane) lb/hr 39.0 37.0 35.0 34.0

 Lead lb/hr 0.038 0.036 0.034 0.033

 Sulfuric Acid Mist lb/hr 0.80 0.76 0.73 0.70

80 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 64.1 61.6 59.6 57.3

Maximum Hourly Emissions per CT

 SO2 lb/hr 3.4 3.2 3.1 2.9

 PM/PM10/PM2.5 lb/hr 48.9 46.8 44.8 42.8

 NOx lb/hr 73.9 69.5 66.3 62.3

 CO lb/hr 56.0 53.0 50.0 47.0

 VOC (as methane) lb/hr 32.0 30.0 29.0 27.0

 Lead lb/hr 0.031 0.030 0.028 0.027

 Sulfuric Acid Mist lb/hr 0.67 0.63 0.60 0.56

70 Percent Load

 Temperature o

F 359 357 355 354

 Velocity ft/sec 57.9 56.0 54.5 52.7

Maximum Hourly Emissions per CT

 SO2 lb/hr 3.1 2.9 2.8 2.7

 PM/PM10/PM2.5 lb/hr 43.8 42.8 40.7 39.7

 NOx lb/hr 67.6 63.6 60.6 57.1

 CO lb/hr 51.0 48.0 46.0 43.0

 VOC (as methane) lb/hr 29.0 28.0 26.0 25.0

 Lead lb/hr 0.029 0.027 0.026 0.024

 Sulfuric Acid Mist lb/hr 0.61 0.57 0.55 0.52

a

 Refer to Appendix B for detailed information on basis of pollutant emission rates and operating data. 

Sources: Siemens, 2011; Golder, 2011.

Combustion Turbine/ HRSG

STACK, OPERATING, AND EMISSION DATA

TABLE 2-2B

Operating and Emission Data a

 for Ambient Temperature 

FOR THE COMBUSTION TURBINES/HRSGS - 

ULTRA LOW-SULFUR DISTILLATE OIL COMBUSTION, SIEMENS H CT

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:tab2-2B
January 2012 

Operating

Scenario

Nat Gas 100 % Load 8,760 7,760 0 

 Fuel Oil 100 % Load 0 1,000 0 

Nat Gas 80 % Load 0 0 8,760 Fuel Oil 80 % Load 0 0 0 Nat Gas 60 % Load 0 0 0 

Nat Gas Fuel Oil Nat Gas Fuel Oil Nat Gas Fuel Oil Fuel Oil 70 % Load 0 0 0 

75 °F 75 °F 75 °F 75 °F 75 °F 75 °F

Pollutant 100% 100% 75% 75% 50% 50% TOTAL 8,760 8,760 8,760 

One Combustion Turbine

 SO2 15.8 3.6 12.6 2.9 9.6 2.6 69.2 63.1 55.0 

 PM/PM10/PM2.5 7.8 19.2 6.3 15.7 4.9 13.5 34.3 40.0 27.5 

 NOx 19.8 70.6 15.5 57.7 11.8 50.3 86.9 112.3 67.8 

 CO 54.3 187.9 42.4 153.7 32.4 134.0 238.0 304.8 185.7 

 VOC (as methane) 3.5 30.7 2.7 25.1 2.1 21.9 15.1 28.7 11.8 

 Sulfuric Acid Mist 3.1 0.7 2.4 0.6 1.9 0.5 13.5 12.3 10.7 

 Lead 0.0 0.033 0.0 0.027 0.0 0.023 0.0 0.016 0.0 

 HAPs 1.23 2.90 0.98 2.38 0.75 2.07 5.4 6.2 4.3 

Three Combustion Turbines

 SO2 47.4 11 37.7 9 28.8 8 208 189 165 

 PM/PM10/PM2.5 23.5 58 18.8 47 14.8 41 102.8 119.9 82.4 

 NOx 59.5 212 46.4 173 35.5 151 261 337 203 

 CO 163.0 564 127.2 461 97.3 402 714 914 557  VOC (as methane) 10.4 92.0 8.1 75.3 6.2 65.6 45.3 86.2 35.4  Sulfuric Acid Mist 9.2 2.1 7.3 1.7 5.6 1.5 40.4 36.8 32.1 

 Lead 0.00 0.10 0.00 0.08 0.00 0.07 0.00 0.049 0.00  HAPs 3.69 8.69 2.93 7.13 2.24 6.22 16.2 18.7 12.9 Sources: MPS, 2011; Golder, 2011.

 - Fuel for Ambient Temperature & Load

TABLE 2-3A

SUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR THE CTS/HRSGS, MPS 501J CTS

Maximum Emissions (tons/y

Opera

Maximum Hourly Emissions (lb/hr)

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January 2012 

Operating

Scenario

Nat Gas 100 % Load 8,760 7,760 0 

 Fuel Oil 100 % Load 0 1,000 0 

Nat Gas 80 % Load 0 0 8,7Fuel Oil 80 % Load 0 0 0 

Nat Gas 60 % Load 000

Nat Gas Fuel Oil Nat Gas Fuel Oil Nat Gas Fuel Oil Fuel Oil 70 % Load 0 0 0 

75 °F 75 °F 75 °F 75 °F 75 °F 75 °F

Pollutant 100% 100% 80% 80% 60% 70% TOTAL 8,760 8,760 8,7One Combustion Turbine

 SO2 14.3 3.8 11.6 3.1 9.5 2.8 62.5 57.2 50

 PM/PM10/PM2.5 13.7 55.0 11.0 44.8 10.5 40.7 60.2 80.8 48 NOx 19.4 81.0 15.8 66.3 13.0 60.6 85.1 115.9 69 CO 30.0 62.0 48.0 50.0 40.0 46.0 131.4 147.4 210

 VOC (as methane) 3.4 35.0 2.8 29.0 2.3 26.0 14.9 30.7 12

 Sulfuric Acid Mist 2.8 0.73 2.3 0.60 1.9 0.55 12.1 11.1 9.

 Lead 0.00 0.034 0.00 0.028 0.00 0.026 0.0 0.017 0.

 HAPs 1.15 3.08 0.94 2.52 0.77 2.31 5.1 6.0 4.

Three Combustion Turbines

 SO2 42.8 11 34.8 9.2 28.6 8.4 187 172 15

 PM/PM10/PM2.5 41.2 165 33.1 134 31.5 122 180.5 242.4 145

 NOx 58.3 243 47.5 199 38.9 182 255 348 20

 CO 90.0 186 144.0 150 120.0 138 394 442 63

 VOC (as methane) 10.2 105.0 8.4 87.0 6.9 78.0 44.7 92.1 36

 Sulfuric Acid Mist 8.3 2.2 6.8 1.8 5.6 1.6 36.4 33.4 29 Lead 0.00 0.103 0.00 0.084 0.00 0.077 0.000 0.052 0.0

 HAPs 3.46 9.23 2.82 7.56 2.31 6.92 15.16 18.04 12.

Sources: Siemens, 2011; Golder, 2011.

 - Fuel for Ambient Temperature & Load

TABLE 2-3B

Ope

SUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR THE CTS/HRSGS, SIEMENS H CTS

Maximum Emissions (ton

Maximum Hourly Emissions (lb/hr)

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January 2012 113-87618

Parameter Units Values

Performance

 Number of Units 1

 Fuel Natural gas

 Heat Input (HHV) a MMBtu/hr 99.77

 Heat Content (HHV-Btu/scf) Btu/scf 1,020

 Fuel Usage scf/hr 97,814

 Rating a lb steam/hr 85,000

 Maximum operation/yr hours 2,000

 Maximum Fuel Usage scf/yr 195,627,451

Exhaust Flow a

 Mass Flow lb/hr 88,066

 Molecular Weight 27.62

 Moisture % 18.17

Stack Parameters a

 Diameter ft 2.75

 Height ft 60

 Temperature o

F 296

 Velocity ft/sec 82

 Flow acfm 29,325

Emissions

 SO2 -Basis b grains S/100 scf 2

 Emissions lb/hr 0.56

TPY 0.56

NOx - Basis a lb/MMBtu 0.050

 Emissions lb/hr 4.99

TPY 4.99

CO - Basis a lb/MMBtu 0.080

 Emissions lb/hr 7.98

TPY 7.98

VOC - Basis c lb/MMscf 5.5

 Emissions lb/MMBtu 0.0054

 lb/hr 0.54

TPY 0.54

PM/PM10/PM2.5 - Basis c,d lb/MMscf 7.6

 Emissions lb/MMBtu 0.0075

 lb/hr 0.74

TPY 0.74

a

 Nebraska Boiler (2005); Golder Associates, (2005); Values are typical.

b

 Typical maximum sulfur content for natural gas

c

 EPA, AP-42, Natural Gas Combustion (March 1998). 

d

 For PM, emissions include filterable and condensables.

TABLE 2-4

PERFORMANCE, STACK PARAMETERS, AND EMISSIONS

 FOR THE AUXILIARY BOILER

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January 2012 113-87618

Parameter Units

Performance

 Number of Units 1 2

 Rating kW 2,250 4,500

 Rating hp 3,200 6,400

 Fuel Diesel Diesel

 Fuel Heat content (HHV) Btu/lb 19,500 19,500

 Fuel density lb/gal 7.06 7.06

 Heat input (HHV) MMBtu/hr 21.01 42

 Fuel usage gal/hr 152.6 305

 Maximum operation/yr hours 100 200

 Maximum fuel usage gal/yr 15,261 30,522

Stack Parameters (typical)

 Diameter ft 1.0 1.0

 Height ft 30 30

 Temperature o

F 916 916

 Flow acfm 17,463 17,463

Emissions

SO2 - Basis %S 0.0015%

 Conversion of S to SO2 % 100

 Molecular weight SO2/ S (64/32) 2

 Emission rate lb/hr 0.032 0.065 

 TPY 0.0016 0.0032

NOx - Basis g/hp-hr 6.9

 Emission rate lb/hr 48.7 97.4

 TPY 2.4 4.9

CO - Basis g/hp-hr 8.5

 Emission rate lb/hr 60.0 120

 TPY 3.0 6.0

VOC - Basis g/hp-hr 1.0

 Emission rate lb/hr 7.1 14.1

 TPY 0.35 0.71

PM/PM10/PM2.5 - Basis g/hp-hr 0.4

 Emission rate lb/hr 2.8 5.6

 TPY 0.14 0.28

Source: FPL, 2011; Golder; 2011.

TABLE 2-5

PERFORMANCE AND EMISSION DATA FOR THE EMERGENCY GENERATORS

Values

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January 2012 113-87618

Parameter Units Values

Performancea

 Number of Units 1

 Fuel Natural gas

 Heat Input (HHV) MMBtu/hr 9.90

 Heat Content (HHV-Btu/scf) Btu/scf 1,020

 Fuel Usage scf/hr 9,706

 Maximum operation/yr hours 8,760

 Maximum Fuel Usage MMscf/yr 85.0

Stack Parameters (typical)

 Diameter ft 1.4

 Height ft 30

 Temperature o

F 500

 Velocity ft/sec 53.6

 Flow acfm 4,950

Emissions

 SO2 -Basis b grains S/100 scf 2

 Emissions lb/MMBtu 0.0056

lb/hr 0.055

 TPY 0.24

NOx - Basis c lb/MMscf 100

 Emission rate lb/MMBtu 0.098

 lb/hr 0.97

 TPY 4.25

CO - Basis c lb/MMscf 84

 Emission rate lb/MMBtu 0.082

 lb/hr 0.82

 TPY 3.57

VOC - Basis c lb/MMscf 5.5

 Emission rate lb/MMBtu 0.0054

 lb/hr 0.053

 TPY 0.23

PM/PM10/PM2.5 - Basis c,d lb/MMscf 7.6

 Emission rate lb/MMBtu 0.0075

 lb/hr 0.074

 TPY 0.32

Note: Project will also have spare heater.

a

 Based on 10 MMBtu/hr (HHV) indirect gas heaters from Hanover Compression 

 Company or equivalent.

b

 Typical maximum for natural gas.

c

 EPA, AP-42, Natural Gas Combustion (March 1998): small boilers < 100 MMBtu/hr. 

d

 For PM, emissions include filterable and condensables.

TABLE 2-6

PERFORMANCE, STACK PARAMETERS, AND EMISSIONS

FOR THE NATURAL GAS FUEL HEATER

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January 2012 113-87618

Parameter Units Values

Performance

 Number 1

 Rating hp 300

 Fuel Diesel

 Fuel Heat content (HHV) MMBtu/hr 19,500

 Fuel density lb/gal 7.06

 Heat input (HHV) a MMBtu/hr 2.32

 Fuel usage gal/hr 16.9

 Maximum operation/yr hours 100

 Maximum fuel usage gal/yr 1,685

Stack Parameters

 Exhaust Flow cfm 1,750

 Stack Velocity ft/sec 60

 Exhaust Temperature o

F 744

 Stack Height ft 17

 Stack Diameter ft 0.79

Emissions

SO2 - Basis %S 0.0015%

 Conversion of S to SO2 % 100

 Molecular weight SO2/S (64/32) 2

 Emission rate lb/hr 0.0036

 TPY 0.00018

NOx - Basis b g/hp-hr 6.8

 Emission rate lb/hr 4.50

 TPY 0.225

CO - Basis b g/hp-hr 2.6

 Emission rate lb/hr 1.7

 TPY 0.086

VOC - Basis b g/hp-hr 1.0

 Emission rate lb/hr 0.66

 TPY 0.033

PM/PM10/PM2.5 - Basis b g/hp-hr 0.4

 Emission rate lb/hr 0.26

 TPY 0.013

a

 2000 gpm fire pump; 300 ft head NFPA 20 Certified; Fairbanks Morse Fire Pumps, 2008.

b

 Emissions based on 40 CFR Part 60 Subpart IIII.

TABLE 2-7

ESTIMATED PERFORMANCE AND EMISSION DATA FOR FIRE PUMP ENGINE

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January 2012 113-87618

Parameter Units

Performance

 Engine Make/Model P Total

 Number of Units 2

 Engine Configuration P

 Fuel P

 Fuel Heat Content (Btu/scf) (LHV) Btu/scf P

 Fuel Heat Content (Btu/scf) (HHV) Btu/scf

 Maximum operation/engine hours

 Ambient temperature o

F P 35 59 75 95 75

 Net output power hp P 6,238 5,927 5,514 4,952 11,028

 Heat input (LHV) MMBtu/hr P 52.82 51.04 48.72 45.70 97.4

 Heat input (HHV) MMBtu/hr 58.52 56.55 53.98 50.64 108.0

 Engine Heat Rate Btu/hp-hr P 8,467 8,612 8,836 9,229 8,836

 Maximum Fuel Usage MMscf/hr 0.0562 0.0543 0.0519 0.0487 0.104

 Maximum Fuel Usage MMscf/yr -- -- 454.4 -- 908.8

Stack Parameters

 Height ft P 20.7 20.7 20.7 20.7

 Diameter ft P 3.50 3.50 3.5 3.5

 Temperature o

F P 917 952 969 994

 Exhaust flow lb/hr P 152,700 145,767 139,138 130,381

 Exhaust flow acfm 91,560 89,625 86,579 82,549

 Exhaust velocity ft/sec 158.6 155.3 150.0 143.0

Emissions

SO2 - Basis grains/100 scf 2 2 2 2 

 Conversion of S to SO2 100 100 100 100

 Ratio Molecular weight SO2/ S (64/32) 2222

 Emission rate lb/hr 0.321 0.311 0.296 0.278 0.59

 TPY 1.41 1.36 1.30 1.22 2.60

 

NOx - Basis a ppmvd @15% O2 15.0 15.0 15.0 15.0

lb/MMBtu (LHV) 0.060 0.060 0.059 0.059

lb/MW-hr 0.68 0.69 0.70 0.72

 Emission rate lb/hr 3.17 3.06 2.87 2.70 5.75

 TPY 13.9 13.4 12.6 11.8 25.2

 

CO - Basis a ppmvd @15% O2 25.0 25.0 25.0 25.0

 lb/MMBtu (LHV) 0.061 0.061 0.060 0.059

 lb/MW-hr 0.68 0.70 0.71 0.73

 Emission rate lb/hr 3.22 3.11 2.92 2.70 5.85

TPY 14.1 13.6 12.8 11.8 25.6

 

UHC - Basis a ppmvd @15% O2 25.0 25.0 25.0 25.0

 lb/MMBtu (LHV) 0.035 0.035 0.034 0.034

lb/MW-hr 0.40 0.40 0.41 0.42

 VOC/UHC % 50% 50% 50% 50%

 VOC Basis ppmvd @15% O2 12.5 12.5 12.5 12.5

lb/MMBtu (LHV) 0.018 0.018 0.017 0.017

 Emission rate lb/hr 0.92 0.89 0.83 0.78 1.66

TPY 4.0 3.9 3.6 3.4 7.3

PM/PM10/PM2.5 - Basis: condensibles b lb/MMBtu 0.0047 0.0047 0.0047 0.0047

 filterables b lb/MMBtu 0.0019 0.0019 0.0019 0.0019

 total b lb/MMBtu 0.0063 0.0063 0.0063 0.0063

 Emission rate lb/hr 0.37 0.36 0.34 0.32 0.68

TPY 1.6 1.6 1.5 1.4 3.0

Sources: FPL, 2011; Golder; 2011.

a Manufacturer's specification

b

 Based on EPA AP-42, Volume I, Section 3.1, Stationary Gas Turbines (April 2000).

TABLE 2-8

PERFORMANCE AND EMISSION DATA FOR THE GAS COMPRESSORS

939.2

8,760

Values

Solar Centaur 50

1

Gas turbine

Natural Gas

1,041

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January 2012 

3 Maximum 2-Year 

 CTs/HRSGs 1 2 1 2 1 Fuel Oil Average from 

with Auxiliary Emergency Natural Gas Gas Fire Pump Storage Existing Units 1 to 4 c 

Pollutant Duct Burners a Boiler b Generators Heater Compressors Engine Tank TOTAL (TPY) 

 SO2 208 0.56 0.003 0.24 2.60 0.00018 NA 211 9,494 

 PM 120 0.74 0.28 0.32 2.98 0.013 NA 124 604 

 PM10 120 0.74 0.28 0.32 2.98 0.013 NA 124 604 

 PM2.5 120 0.74 0.28 0.32 2.98 0.01 NA 124 402 

 NOx 337 4.99 4.87 4.25 25.2 0.22 NA 376 4,260 

 CO 914 7.98 6.00 3.57 25.6 0.086 NA 958 885 

 VOC (as methane) 86.2 0.54 0.71 0.23 7.3 0.033 5.82 100.8 76.9 

 Sulfuric Acid Mist 40.4 Neg. Neg. Neg. Neg. Neg. NA 40.4 422.3 

Lead 0.049 Neg. Neg. Neg. Neg. Neg. NA 0.049 0.10 

Greenhouse Gases (CO2e) 4,410,327 11,670 687 5,072 55,313 15.2 NA 4,483,085 2,551,038 

a Based on oil-firing for: 1,000b An auxiliary boiler is only required to supply steam to the MPS 501J CT during startup.c Based on actual emissions from Annual Operating Reports from 2006-2010.

Note: Neg.= negligible; NA= not applicableSource: Golder, 2011.

hours (maximum).

Maximum Potential Annual Emissions (TPY) Netting Calcu

TABLE 2-9A

SUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR PEEC, MPS 501J CTS

PEEC Project

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January 2012 

Maximum 2-Year 

 2 1 2 1 Fuel Oil Average from 

3 Emergency Natural Gas Gas Fire Pump Storage Existing Units 1 to 4 b 

Pollutant CTs/HRSGs a Generators Heater Compressors Engine Tank TOTAL (TPY) 

 SO2 187 0.003 0.24 2.60 0.00018 NA 190 9,494 

 PM 242 0.28 0.32 2.98 0.013 NA 246 604 

 PM10 242 0.28 0.32 2.98 0.013 NA 246 604 

 PM2.5 242 0.28 0.32 2.98 0.013 NA 246 402 

 NOx 348 4.87 4.25 25.2 0.22 NA 382 4,260 

 CO 631 6.00 3.57 25.6 0.086 NA 666 885 

 VOC (as methane) 92.1 0.71 0.23 7.3 0.033 5.82 106 76.9 

 Sulfuric Acid Mist 36.4 Neg. Neg. Neg. Neg. NA 36.4 422.3 

Lead 0.052 Neg. Neg. Neg. Neg. NA 0.052 0.10 

Greenhouse Gases (CO2e) 4,058,754 687 5,072 55,313 15.2 NA 4,119,841.35 2,551,038 

a Based on oil-firing for: 1,000b Based on actual emissions from Annual Operating Reports from 2006-2010.

Note: Neg.= negligible; NA= not applicable

hours (maximum).

Maximum Potential Annual Emissions (TPY) Netting Calcula

TABLE 2-9B

SUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR PEEC, SIEMENS H CTS

PEEC Project

Source: Golder, 2011.

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab2-9B Siemens
January 2012 

12 1 2 1 Fuel Oil 

3 Auxiliary Emergency Natural Gas Gas Fire Pump Storage 

Pollutant CTs/HRSGs Boiler b Generators Heater Compressors Engine Tank T

MPS 501J CTs

Total HAPs 18.7 0.0088 0.003 0.004 0.45 0.0002 NA 

Single HAP a 7.9 0.0073 0.0002 0.003 0.34 0.00001 NA 

Siemens H CTs

Total HAPs 18.0 NA 0.003 0.004 0.45 0.0002 NA 

Single HAP a 6.9 NA 0.0002 0.003 0.34 0.00001 NA 

a Based on formaldehyde emissionsb An auxiliary boiler is only required to supply steam to the MPS 501J CT during startup.

Note: NA= not applicable.Source: Golder, 2011.

TABLE 2-10

SUMMARY OF MAXIMUM POTENTIAL ANNUAL HAP EMISSIONS FOR PEEC

Maximum Potential Annual Emissions (TPY)

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January 2012 

Pollutant Averaging Time

Primary 

Standard

Secondary 

Standard Florida AAQS (μg/m3) 

Particulate Matter Annual Arithmetic Mean NA NA 50  (PM10) a 24-Hour Maximum 150 150 150 

Particulate Matter Annual Arithmetic Mean 15 15 15 

(PM2.5) a 24-Hour Maximum 35 35 35 

Sulfur Dioxide b Annual Arithmetic Mean 80 NA 60 

24-Hour Maximum 365 NA 260 3‐Hour Maximum NA 1,300 1,300 1‐Hour Maximum 197 NA NA 

Carbon Monoxide 8‐Hour Maximum 10,000 10,000 10,000 

1‐Hour Maximum 40,000 40,000 40,000 

Nitrogen Dioxide c Annual Arithmetic Mean 100 100 100 

1‐Hour Maximum 188 NA NA 

Ozone d 1‐Hour Maximum NA NA 235 

8-Hour Maximum 147 147 NA 

Lead Rolling 3-Month Average 0.15 0.15 0.15 

Note: NA = not applicable.  AAQS = ambient air quality standard.

a On October 17, 2006, EPA promulgated revised PM10 and PM2.5 AAQS; the PM2.5 AAQS had been promulgated on July 18, 1997. For PM10, the annual s

 The 24-hour PM2.5 standard was revised to 35 μg/m3 based on the 3-year averages of the 98th percentile values. The annual PM2.5 standard of 15 μg/m3, 3

b On June 23, 2010, EPA promulgated the 1-hour SO2 standard at a level of 75 parts per billion (ppb), based on the 3-year average of the annual 99th percen

 (effective August 23, 2010). EPA is also revoking both the existing 24-hour and annual primary SO2 standards, effective one year after the designation of 

c On February 9, 2010, EPA promulgated the 1-hour NO2 standard at a level of 100 ppb, based on the 3-year average of the annual 99th percentile of 1-hour 

d On March 27, 2008, EPA promulgated revised AAQS for ozone. The O3 standard was modified to be 0.075 ppm (147 μg/m3) for the 8-hour average; ach

e For NO2 and SO2 1-hour averaging period, an interim Class II significant impact level is shown.

Sources: Federal Register, Vol. 43, No. 118, June 19, 1978; 40 CFR 50; 40 CFR 52.21; Florida Chapter 62.204, F.A.C. Golder, 2011.

TABLE 3-1

NATIONAL AND STATE AAQS, ALLOWABLE PSD INCREMENTS, AND SIGNIFICANT 

 AAQS (μg/m3)

National

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January 2012 113-87632

Significant De Minimis

Emission Monitoring

Regulated Rate Concentration

Pollutant Under (TPY) (μg/m3

) a

Sulfur Dioxide NAAQS, NSPS 40 13, 24-hour

Particulate Matter [PM(TSP)] NSPS 25 NA

Particulate Matter (PM10) NAAQS 15 10, 24-hour

Particulate Matter (PM2.5) c NAAQS 10, or 4, 24-Hour

NAAQS 40 of SO2, or NA

NAAQS 40 of NOx NA

Nitrogen Dioxide NAAQS, NSPS 40 14, annual

Carbon Monoxide NAAQS, NSPS 100 575, 8-hour

Volatile Organic Compounds (Ozone) NAAQS, NSPS 40 100 TPYb

Lead NAAQS 0.6 0.1, 3-month

Sulfuric Acid Mist NSPS 7 NM

Total Fluorides NSPS 3 0.25, 24-hour

Total Reduced Sulfur NSPS 10 10, 1-hour

Reduced Sulfur Compounds NSPS 10 10, 1-hour

Hydrogen Sulfide NSPS 10 0.2, 1-hour

Mercury NESHAP 0.1 0.25, 24-hour

MWC Organics (dioxin/furans) NSPS 3.5x10-6 NM

MWC Metals (as PM) NSPS 15 NM

MWC Acid Gases (SO2 + HCl) NSPS 40 NM

MSW Landfill Gases (as NMOC) NSPS 50 NM

Greenhouse Gases d -- 0 (mass basis), and NM

-- 75,000 (CO2e basis) NM

Note: Ambient monitoring requirements for any pollutants may be exempted if the

 impact of the increase is less than de minimis monitoring concentrations.

NA = not applicable

NM = no ambient measurement method established; therefore, no de minimis 

concentration has been established

mg/m3

 = micrograms per cubic meter

MWC = municipal waste combustor

MSW = municipal solid waste

NMOC = non-methane organic compounds

a

 Short-term concentrations are not to be exceeded

b

 No de minimis concentration; an increase in VOC OR NOx emissions of 100 TPY or more

will require a monitoring analysis for ozone

c

 Any emission rate of these pollutants.

d

 On July 20, 2011, biogenic CO2 emissions were deferred from consideration in the 

significant emission rates for three years.

Source: 40 CFR 52.21

 Rule 62-212.400, F.A.C.

DE MINIMIS MONITORING CONCENTRATIONS

TABLE 3-2

PSD SIGNIFICANT EMISSION RATES AND

Table 3-2_SER_DEMINIMIS.xlsx
January 2012 113-87618

Table 3-3rev1.docx 

TABLE 3-3 

MAXIMUM EMISSION CHANGES DUE TO PEEC, 

INCLUDING EMISSION REDUCTIONS DUE TO THE EXISTING UNITS 1 THROUGH 4 

AT PORT EVERGLADES PLANT, 

COMPARED TO THE PSD SIGNIFICANT EMISSION RATES 

Pollutant Emissions 

Pollutant 

Net Emission 

Changes*

(TPY) 

Significant 

Emission Rate 

(TPY) PSD Review 

Sulfur Dioxide −9,283 40 No 

Particulate Matter [PM (TSP)] −358 25 No 

Particulate Matter (PM10) −358 15 No 

Particulate Matter (PM2.5) −156 15 No 

Nitrogen Dioxide -3,878 40 No 

Carbon Monoxide 73 100 No 

Volatile Organic Compounds 29.2 40 No 

Lead −0.047 0.6 No 

Sulfuric Acid Mist −382 7 No 

Total Fluorides NEG 3 No 

Total Reduced Sulfur NEG 10 No 

Reduced Sulfur Compounds NEG 10 No 

Hydrogen Sulfide NEG 10 No 

Mercury NEG 0.1 No 

Greenhouse Gases 1,932,047 100,000 Yes 

Note: NEG = Negligible. 

* A. Based on emissions from operating at baseload at 75°F for all pollutants except SO2: 

 100-percent load, natural gas – 7,760 hours 

 100-percent load, oil firing – 1,000 hours 

B. SO2 emissions based on operations at baseload at 75°F: 

 100-percent load, natural gas – 8,760 hours 

Includes emissions from the fuel heater, emergency generators, auxiliary boiler, fire pump engine, 

fuel oil storage tank, and gas compressor station (see Tables 2-9A and B, which present the 

maximum potential emissions for PEEC) and emission reductions from the existing Units 1 

through 4 at Port Everglades Plant. 
January 2012 

Operating Proposed

Pollutant CT(s) Fuel Mode Emission Limits Compliance MethodNOx J and H Natural Gas All 2 ppmvd at 15% O2 Initial: EPA Methods- 7E or 20, Continuous: CEM 

J and H ULSD All 8 ppmvd at 15% O2 Initial: EPA Methods- 7E or 20, Continuous: CEM 

CO J Natural Gas Baseload 9 ppmvd at 15% O2 Initial: EPA Method 10

ULSD Baseload 35 ppmvd at 15% O2 Initial: EPA Method 10

H Natural Gas Baseload 5 ppmvd at 15% O2 Initial: EPA Method 10

ULSD Baseload 10 ppmvd at 15% O2 Initial: EPA Method 10

VOC J Natural Gas Baseload 1 ppmvd at 15% O2 Initial Only: EPA Methods 18 or 25a 

ULSD Baseload 10 ppmvd at 15% O2 Initial Only: EPA Methods 18 or 25a

H Natural Gas Baseload 1 ppmvd at 15% O2 Initial Only: EPA Methods 18 or 25a 

ULSD Baseload 10 ppmvd at 15% O2 Initial Only: EPA Methods 18 or 25a

PM/PM10 J and H Natural Gas All 10% Opacity Initial/Annual: EPA Method 9

J and H ULSD All 10% Opacity Initial/Annual: EPA Method 9

SO2 and SAM J and H Natural Gas All 2 grains S/100 scf Initial/Annual: 40 CFR Part 75 Fuel Sampling

J and H ULSD All 0.0015% S Initial/Annual: 40 CFR Part 75 Fuel Sampling

GHG J and H Natural Gas All 877 lb CO2e /MW-hr 12-month rolling average; CO2e based on 40 CFR P

 & ULSD MW-hr based on 40 CFR Part Subpart KKKK

Note: CT = combustion turbine; HRSG = heat recovery steam generator; ULSD = ultra low sulfur distillate light oil. J = MPS 501J CT; H = Siemens H CT.

TABLE 4-1

PROPOSED EMISSION LIMITS FOR CTS/HRSGS FOR PEEC

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\Table 4-1_Proposed Emis Limits CT_HRSGrev1.xlsx
January 2012 

3-Hour 8-Hou

Pollutant/ AIRS Measurement Period 2nd 2nd Site No. Location County Year Months Highest Highest Percentile Highest Highest Highest HiSulfur dioxide (SO2) c Florida AAQS NA NA 0.075 ppm NA 0.5 ppm NA 

99th

12-011-0010 Fort Lauderdale, Broward 2010 Jan-Dec 0.076 0.056 0.038 -- -- NA 

Lincoln Park Elementary School 2009 Jan-Dec 0.096 0.072 -- 0.057 0.057 NA 

2008 Jan-Dec 0.031 0.021 -- 0.019 0.014 NA 

Nitrogen dioxide (NO2) d Florida AAQS NA NA 0.1 ppm NA NA NA 

98th

12-011-8002 Dania Broward 2010 Jan-Dec 0.065 0.054 0.049 NA NA NA 

7000 N. Ocean Drive 2009 Jan-Dec 0.066 0.050 -- NA NA NA 

2008 Jan-Dec 0.058 0.055 -- NA NA NA 

Particulate Matter (PM10 ) a Florida AAQS NA NA NA NA NA 

12-011-0010 Fort Lauderdale, Broward 2010 Jan-Dec NA NA NA NA NA NA 

Lincoln Park Elementary School 2009 Jan-Dec NA NA NA NA NA NA 

2008 Jan-Dec NA NA NA NA NA NA 

12-011-3002 Hollywood Broward 2009 Jan-Dec NA NA NA NA NA NA 

2701 Plunkett Street 2008 Jan-Dec NA NA NA NA NA NA 

Particulate Matter (PM2.5) a Florida AAQS NA NA NA NA NA 

12-011-2003 Pompano Beach Broward 2010 Jan-Dec NA NA NA NA NA NA 

1951 NE 48th Street 2009 Jan-Dec NA NA NA NA NA NA 

2008 Jan-Dec NA NA NA NA NA NA 

12-011-3002 Hollywood Broward 2009 Jan-Dec NA NA NA NA NA NA 

2701 Plunkett Street 2008 Jan-Dec NA NA NA NA NA NA 

Ozone (O3) b Florida AAQS NA 0.12 ppm NA NA NA 

12-011-8002 Dania Broward 2010 Jan-Dec 0.107 0.074 NA NA NA NA 

7000 N. Ocean Drive 2009 Jan-Dec 0.077 0.073 NA NA NA NA 

2008 Jan-Dec 0.083 0.082 NA NA NA NA 

Carbon monoxide (CO) Florida AAQS NA 35 ppm NA NA NA 9 

12-011-0010 Fort Lauderdale, Broward 2010 Jan-Dec 2.3 2.3 NA NA NA 1.8 

Lincoln Park Elementary School 2009 Jan-Dec 3.1 2.8 NA NA NA 2.0 

2008 Jan-Dec 3.2 3.2 NA NA NA 2.5 

12-011-3002 Hollywood Broward 2009 Jan-Dec 1.8 1.8 NA NA NA 1.5 

2701 Plunkett Street 2008 Jan-Dec 2.4 2.1 NA NA NA 1.7 

Note: NA = not applicable. AAQS = ambient air quality standard.

a On October 17, 2006, EPA promulgated revised PM10 and PM2.5 AAQS; the PM2.5 AAQS had been promulgated on July 18, 1997. For PM10, the annual standard was revoked and the 24-hour s

 The 24-hour PM2.5 standard was revised to 35 μg/m3 based on the 3-year averages of the 98th percentile values. The annual PM2.5 standard of 15 μg/m3, 3-year averages at community monitors

b On March 27, 2008, EPA promulgated revised AAQS for ozone. The O3 standard was modified to be 0.075 ppm for the 8-hour average; achieved when the 3-year average of 99th percentile valu

 c On June 23, 2010, EPA promulgated the 1-hour SO2 standard at a level of 75 parts per billion (ppb), based on the 3-year average of the annual 99th percentile of 1-hour daily maximum concentr

 EPA is also revoking both the existing 24-hour and annual primary SO2 standards, effective one year after the designation of an area, pursuant to section 107 of the Clean Air Act.

 d On February 9, 2010, EPA promulgated the 1-hour NO2 standard at a level of 100 ppb, based on the 3-year average of the annual 99th percentile of 1-hour daily maximum concentrations (effect

TABLE 5-1

SUMMARY OF MAXIMUM MEASURED SO2, NO2, PM10, PM2.5, O3, AND CO CONCENTRATION

REPRESENTATIVE OF PEEC PROJECT, 2008 THROUGH 2010

Measured Conc

1-Hour 

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Tab5-1 MonitoringData
January 2012 

Averaging Existing 

Pollutant Time Units 1, 2, 3 & 4 Only PEEC Only b Units 1, 2, 3 & 4 PEEC b 

SO2 Annual 29.8 0.4 32.4 3.0 

24-Hour 200 3.3 221 24.2 

3-Hour 511 5.5 604 98.5 

1-Hour NA 6.0 NA 106 

PM10 Annual 1.1 0.6 19.1 18.7 

24-Hour 6.8 4.9 55.8 53.9 

PM2.5 Annual 0.7 0.6 7.8 7.7 

24-Hour 4.5 4.9 20.5 20.9 

NO2 Annual 9.3 1.4 21.1 13.3 

1-Hour NA 30.8 NA 123 

CO 8-Hour 14.2 34.0 2314 2,334 

1-Hour 21.1 38.3 3203 3,220 

a Background concentration based on the maximum measured concentration from representative air quality data for the Site.b PEEC sources include the 3 CTs/HRSGs, fuel heater, and gas compressors.

TABLE 6-1

SUMMARY OF PREDICTED POLLUTANT CONCENTRATIONS 

FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT AND THE PEEC PR

COMPARED TO AMBIENT AIR QUALITY STANDARDS

Maximum Concentration (ug/m3)

Total Concentration (ug/m3)

including Background a 

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-1
January 2012 113-87618 

Table 6-2.docx 

TABLE 6-2 

MAJOR FEATURES OF THE AERMOD MODEL, VERSION 11353

AERMOD Model Features 

• Plume dispersion/growth rates are determined by the profile of vertical and horizontal turbulence, vary 

with height, and use a continuous growth function. 

• In a convective atmosphere, uses three separate algorithms to describe plume behavior as it comes in 

contact with the mixed layer lid; in a stable atmosphere uses a mechanically mixed layer near the surface. 

• Polar or Cartesian coordinate systems for receptor locations can be included directly or by an external 

file reference. 

• Urban model dispersion is input as a function of city size and population density; sources can also be 

modeled individually as urban sources. 

• Stable plume rise: uses Briggs equations with winds and temperature gradients at stack top up to half way 

up to plume rise. Convective plume rise: plume superimposed on random convective velocities. 

• Procedures suggested by Briggs (1974) for evaluating stack-tip downwash. 

• Has capability of simulating point, volume, area, and multi-sized area sources. 

• Accounts for the effects of vertical variations in wind and turbulence (Brower et al., 1998). 

• Uses measured and computed boundary layer parameters and similarity relationships to develop vertical 

profiles of wind, temperature, and turbulence (Brower et al., 1998). 

• Concentration estimates for 1-hour to annual average times. 

• Creates vertical profiles of wind, temperature, and turbulence using all available measurement levels. 

• Terrain features are depicted by use of a controlling hill elevation and a receptor point elevation. 

• Modeling domain surface characteristics are determined by selected direction and month/season values 

of surface roughness length, Albedo, and Bowen ratio. 

• Contains both a mechanical and convective mixed layer height, the latter based on the hourly 

accumulation of sensible heat flux. 

• The method of Pasquill (1976) to account for buoyancy-induced dispersion. 

• A default regulatory option to set various model options and parameters to EPA-recommended values. 

• Contains procedures for calm-wind and missing data for the processing of short term averages. 

Note: AERMOD = The American Meteorological Society and Environmental Protection Agency Regulatory 

Model. 

Source: EPA, 2011. 
January 2012 113-87618

Parameter Units Unit 1 Unit 2 Unit 3 Unit 4

 

Stack Data a

Height feet 343 343 343 343

Diameter feet 14.0 14.0 18.1 18.1

Operating Data a 

Heat inputb MMBtu/hr 2,300 2,300 4,000 4,000

Temperature o

F 289 289 287 287

Flow rate acfm 813,929 813,929 1,263,181 1,263,181

Velocity ft/sec 88.1 88.1 81.8 81.8

Maximum Hourly Emissions

SO2 lb/MMBtu b 1.10 1.10 1.10 1.10

lb/hr 2,530 2,530 4,400 4,400

PM/PM10 lb/MMBtu a,c 0.039 0.039 0.039 0.039

lb/hr 89 89 155 155

PM2.5 lb/MMBtu e 0.026 0.026 0.026 0.026

lb/hr 59 59 103 103

NOx lb/MMBtu a 0.36 0.36 0.53 0.53

lb/hr 828 828 2,120 2,120

CO lb/MMBtu d 0.03 0.03 0.03 0.03

lb/hr 75.7 75.7 132.5 132.5

a Stack and operating parameters based on Permit No. 0110036-007-AV (2009) and Title V permit application (2008).

b Based on use of maximum historical sulfur fuel oil content of 1 percent.

c Based on 0.1 lb/MMBtu (soot-blowing) for 3 hr/day and 0.03 lb/MMBtu (steady-state) for 21 hr/day.

d Based on AP-42 emission factor for combustion for No. 6 fuel oil (Table 1.3-1, U.S. EPA, 1998) 

and 152 MMBtu/1,000 gal: CO: 5 lb/1000 gal

e Based on AP-42 emission factor for combustion for No. 6 fuel oil with ESP (Table 1.3-1, U.S. EPA, 1998).

TABLE 6-3

EXISTING FPL PORT EVERGLADES PLANT, UNITS 1 THROUGH 4

STACK, OPERATING, AND EMISSIONS DATA

Operating and Emission Data

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-3 ExistingData
January 2012 

Averaging Concentration Existing 

Pollutant Time Rank Units 1, 2, 3 & 4 Only Background Total 

SO2 Annual Highest 29.8 2.6 32.4 

24-Hour Highest, 2nd-Highest 200 20.9 221 

3-Hour Highest, 2nd-Highest 511 93.0 604 

PM10 Annual Highest 1.1 18.1 19.1 

24-Hour Highest, 6th-Highest 6.8 49.0 55.8 

PM2.5 Annual Highest 0.7 7.1 7.8 

24-Hour Highest, 6th-Highest 4.5 16.0 20.5 

NO2 Annual Highest 9.3 11.9 21.1 

CO 8-Hour Highest, 2nd-Highest 14.2 2,300 2,314 

1-Hour Highest, 2nd-Highest 21.1 3,182 3,203 

TABLE 6-4

SUMMARY OF PREDICTED POLLUTANT CONCENTRATIONS 

FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT

COMPARED TO AMBIENT AIR QUALITY STANDARDS

Maximum Concentration (ug/m3)

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-4 Existing Impacts
January 2012 113-87618

Averaging 

Pollutant Time Natural Gas Fuel Oil Maximum Natural Gas Fuel Oil Maximum

CTs Only a 

SO2 Annual 0.34 0.04 0.34 0.31 0.04 0.31

24-Hour 3.29 0.34 3.29 2.97 0.34 2.97

3-Hour 5.49 0.67 5.49 4.98 0.68 4.98

1-Hour 6.02 0.72 6.02 5.28 0.73 5.28

PM10/PM2.5 Annual 0.17 0.22 0.18 0.30 0.63 0.34

24-Hour 1.63 1.81 1.81 2.84 4.95 4.95

NO2 Annual c 0.32 0.63 0.36 0.32 0.70 0.36

1-Hour c 6.05 11.30 11.30 5.75 12.56 12.56

CO 8-Hour 17.4 33.1 33.1 19.5 10.6 19.5

1-Hour 20.7 37.6 37.6 21.9 12.0 21.9

CTs and Fuel Heater b

SO2 Annual 0.36 NM 0.36 0.32 NM 0.32

24-Hour 3.29 NM 3.29 2.97 NM 2.97

3-Hour 5.49 NM 5.49 4.98 NM 4.98

1-Hour 6.02 NM 6.02 5.28 NM 5.28

PM10/PM2.5 Annual NM 0.22 0.22 NM 0.63 0.63

24-Hour NM 1.81 1.81 NM 4.95 4.95

NO2 Annual c NM 0.90 0.90 NM 1.10 1.10

1-Hour c NM 27.6 27.6 NM 27.6 27.6

CO 8-Hour NM 33.1 33.1 19.5 NM 19.5

1-Hour NM 37.6 37.6 21.9 NM 21.9

CTs, Fuel Heater, and Gas Compressors b 

SO2 Annual 0.40 NM 0.40 0.36 NM 0.36

24-Hour 3.29 NM 3.29 2.97 NM 2.97

3-Hour 5.49 NM 5.49 4.98 NM 4.98

1-Hour 6.02 NM 6.02 5.28 NM 5.28

PM10/PM2.5 Annual NM 0.25 0.25 NM 0.63 0.63

24-Hour NM 1.81 1.81 NM 4.95 4.95

NO2 Annual c NM 1.12 1.12 NM 1.43 1.43

1-Hour c NM 30.8 30.8 NM 30.8 30.8

CO 8-Hour NM 33.1 33.1 34.0 NM 34.0

1-Hour NM 38.3 38.3 38.0 NM 38.0

a Based on pollutant emissions for each vendor. Impacts are based on highest impacts predicted for CTs only.

Maximum annual average concentrations for the CTs are based on prorating the maximum impacts 

for each operation by the following maximum number of hours requested for that operation: 

Pollutant Natural Gas Fuel Oil Total

SO2 8,760 0 8,760

PM10/PM2.5 7,760 1,000 8,760

NO2 7,760 1,000 8,760

b

c NOx to NO2 conversion factor based on EPA Modeling Guidelines: 

75 % for annual average;

80 % for 1-hour average.

Note: NM = Not Modeled.

 SUMMARY OF MAXIMUM POLLUTANT CONCENTRATIONS PREDICTED

TABLE 6-5

FOR NATURAL GAS- AND DISTILLATE FUEL OIL-FIRING FOR PEEC

Concentration (μg/m3

) 

Maximum Predicted

MPS J CTs Siemens H CTs

Maximum Predicted

Concentration (μg/m3) 

Hours for Each Operation

Based on modeling the CTs for the fuel which produced the maximum impacts for the CTs only; as a conservative estimate 

of air impacts, the higher predicted concentration from the highest impacts for the CTs only or the highest concentrations, 

accounting for the format of the standard, for the CTs with other project sources (e.g., highest, second-highest 3-hour 

impacts).

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-5
January 2012 113-87618

Averaging AAQS

Pollutant Time PEEC a Background b Total PEEC a Background b Total (μg/m3

)

CTs and Fuel Heater

SO2 Annual 0.36 2.6 2.97 0.32 2.6 2.93 60

24-Hour 3.29 20.9 24.2 2.97 20.9 23.8 260

3-Hour 5.49 93.0 98.5 4.98 93.0 98.0 1,300

1-Hour 6.02 99.6 105.6 5.28 99.6 104.8 197

PM10 Annual 0.22 18.1 18.3 0.63 18.1 18.7 50

24-Hour 1.81 49.0 50.8 4.95 49.0 53.9 150

PM2.5 Annual 0.22 7.1 7.3 0.63 7.1 7.7 15

24-Hour 1.81 16.0 17.8 4.95 16.0 20.9 35

NO2 Annual 0.90 11.9 12.8 1.10 11.9 13.0 100

1-Hour 27.59 92.2 119.8 27.59 92.2 119.8 188

 

CO 8-Hour 33.1 2,300 2,333 19.5 2,300 2,320 10,000

1-Hour 37.6 3,182 3,219 21.9 3,182 3,204 40,000

CTs, Fuel Heater, and Gas Compressors

SO2 Annual 0.40 2.6 3.01 0.36 2.6 2.97 60

24-Hour 3.29 20.9 24.2 2.97 20.9 23.8 260

3-Hour 5.49 93.0 98.5 4.98 93.0 98.0 1,300

1-Hour 6.02 99.6 105.6 5.28 99.6 104.8 197

PM10 Annual 0.25 18.1 18.3 0.63 18.1 18.7 50

24-Hour 1.81 49.0 50.8 4.95 49.0 53.9 150

PM2.5 Annual 0.25 7.1 7.3 0.63 7.1 7.7 15

24-Hour 1.81 16.0 17.8 4.95 16.0 20.9 35

NO2 Annual 1.12 11.9 13.0 1.43 11.9 13.3 100

1-Hour 30.79 92.2 123.0 30.79 92.2 123.0 188

 

CO 8-Hour 33.1 2,300 2,333 34.0 2,300 2,334 10,000

1-Hour 38.3 3,182 3,220 38.0 3,182 3,220 40,000

a Based on highest concentrations predicted for the project in Table 6-5.

b Based on concentrations measured at representative monitoring stations nearest the Site.

Concentration (μg/m3

) Concentration (μg/m3) 

MPS J CTs Siemens H CTs

TABLE 6-6

MAXIMUM POLLUTANT CONCENTRATIONS PREDICTED FOR PEEC

COMPARED TO THE AAQS

Maximum Predicted Maximum Predicted

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-6
January 2012 

A

Maximum Background Total Qua

Emission Averaging Concentration a,d Concentration b Concentration 

Pollutant Rate Units Time (ug/m3) (ug/m3) (ug/m3) 

SO2 0.56 TPY Annual 0.033 2.6 2.6 

0.56 lb/hr 24-Hour 1.4 20.9 22.3 

0.56 lb/hr 3-Hour 2.8 93.0 95.8 

0.56 lb/hr 1-Hour 3.9 99.6 103.5 

PM10 0.74 TPY Annual 0.04 18.1 18.1 

0.74 lb/hr 24-Hour 1.8 49.0 50.8 

PM2.5 0.74 TPY Annual 0.04 7.1 7.1 

0.74 lb/hr 24-Hour 1.8 16.0 17.8 

NOx c 4.99 TPY Annual 0.22 11.9 12.1 

 4.99 lb/hr 1-Hour 27.9 92.2 120.1 

CO 7.98 lb/hr 8-Hour 28.8 2,300 2,329 

7.98 lb/hr 1-Hour 55.8 3,182 3,238 

a Concentrations are based on highest concentrations predicted using 5 years of meteorological data from 2006 to 2010 of surface and upper air data 

from the National Weather Service stations at Ft. Lauderdale-Hollywood International Airport and Florida International University (FIU).Based on highest annual and highest short-term average concentrations predicted for the units, by ratioing modeled rate to pollutant specific rate:

Modeled Predicted

Rate Averaging Concentration

(lb/hr) Time (ug/m3)

79.37 Annual 20.4

24-Hour 197.2

8-Hour 286.13-Hour 393.91-Hour 555.3

b Based on highest concentrations measured at representative monitoring stations nearest the site.c NOx to NO2 conversion factor of 0.75 and 0.80 applied to modeled annual and 1-hour NOx impacts, respectively, based on EPA Modeling Guidelines.d Based on 2,000 hours/yr operation.

TABLE 6-7

SUMMARY OF POLLUTANT CONCENTRATIONS PREDICTED FOR THE PEEC AUXILIARY BOILER

COMPARED TO EPA AMBIENT AIR QUALITY STANDARDS

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-7
January 2011 113-87618

Averaging Existing

Pollutant Time MPS J CTs Siemens H CTs Units 1 - 4

SO2 Annual 0.0035 0.0032 0.79

24-Hour 0.084 0.075 10.5

3-Hour 0.32 0.29 42.1

1-Hour 0.62 0.56 90.9

PM10 Annual 0.0038 0.011 0.028

24-Hour 0.055 0.16 0.37

PM2.5 Annual 0.0038 0.011 0.028

24-Hour 0.055 0.16 0.37

NO2 Annual b 0.011 0.012 0.25

1-Hour b 1.73 1.93 30.6

SO2 Annual 0.0036 0.0033 0.79

24-Hour 0.087 0.078 10.5

3-Hour 0.33 0.30 42.1

1-Hour 0.64 0.58 90.9

PM10 Annual 0.0038 0.011 0.028

24-Hour 0.055 0.16 0.37

PM2.5 Annual 0.0038 0.011 0.028

24-Hour 0.055 0.16 0.37

NO2 Annual b 0.011 0.013 0.25

1-Hour b 1.84 2.04 30.6

a Based on CT baseload operations at 35 o

F which has the highest emissions; 

for NO2 and PM10/PM2.5, oil-firing; for SO2, natural gas-firing.

b NOx to NO2 conversion factor based on EPA Modeling Guidelines: 

75 % for annual average;

80 % for 1-hour average.

TABLE 6-8

EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT AND THE PEEC PROJECT

CTs, Fuel Heater, and Gas Compressors

PEEC a 

Maximum Predicted Concentration (μg/m3) 

CTs and Fuel Heater

MAXIMUM POLLUTANT CONCENTRATIONS PREDICTED FOR THE

AT THE PSD CLASS I AREA OF THE EVERGLADES NATIONAL PARK

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\PSD 5,6 SCA 6 - AAQS_12Jan2011.xlsx:Permit Tab6-8 (add)
FIGURES 

 
^

ATLANTIC 

OCEAN

P A L M

B E A C H B E A C H

C O U N T Y C O U N T Y

C O U N T Y C O U N T Y

H E N D R Y H E N D R Y

C O U N T Y C O U N T Y

C O L L I E R C O L L I E R

B R O W A R D B R O W A R D

C O U N T Y C O U N T Y

M I A M I - D A D E M I A M I - D A D E

C O U N T Y C O U N T Y

£¤1 £¤41

£¤441 £¤441

£¤1£¤1 £¤1

£¤41

£¤1

£¤1

£¤27

")112

")93

")836

")

")924

821

")836

")91

")869

§ ̈¦395

§ ̈¦195

§ ̈¦75

§ ̈¦595

§ ̈¦95

Port Everglades Plant and

Port Everglades

Energy Center Site

F:\PROJECTS\2011 PROJ\113-87618_PortEvergladesEnergyCenterSCA\A_0100_Preparation_of_SCA\MapDocuments\113-87618A007 FEMA.mxd

3

7 3.50

Miles

GIS

REVIEW

DESIGN SCALE:

CHECK

0

PROJECT No. 113-87618 FILE No. 113-87618A028

NRL

RCM AS SHOWN

FIGURE 1-1

PROJECT

TITLE

FPL

PORT EVERGLADES ENERGY CENTER

GENERAL LOCATION OF THE 

FPL PORT EVERGLADES PLANT AND 

PORT EVERGLADES ENERGY CENTER

REV.

1/13/2012

12/21/2011

REV. DATE DES REVISION DESCRIPTION GIS CHK RVW

REFERENCES

1. Port Everglades Plant and Port Everglades Energy Center Site

Location, FPL 2011

2. Municipalities, Broward County Florida, 2011, Plam Beach

County Florida, 2010, and Miami Dade County Florida. 2009

3. Roads, Florida Department of Transportation, 2011

AREA MAP

LEGEND

^ BROWARD

^

^ Port Everglades Plant and

Port Everglades Energy Center Site

KFK

RCM

1/13/2012

1/13/2012

Process Flow Legend

Solid/LiquidGasSteam

November 2011 Figure 2-2. Process Flow Diagram for Each CT/HRSG TrainBaseload Operation, Turbine Inlet Temperature of 75°FFPL Port Everglades Energy Center, Broward County, FloridaSource: MPS, 2011; Siemens, 2011; Golder, 2011.

COMBUSTOR

COMBUSTION TURBINE 

(CT)

NATURAL GAS

OR ULTRA

LOW-SULFUR

LIGHT OIL

Heat Recovery S

Generator (HRS

GENERATOR

ELECTRICITY

AIR

WATER FOR 

NOX CONTROL 

(LIGHT OIL)

STEAM TO 

STEAM/ELECTRIC 

GENERATOR

Parameters Units Fuel MPS 501J Class Siemens H Inlet Air lb/hr Gas 4,625,400 4,696,1

lb/hr Oil 4,639,600 4,767,9

CT Heat Input MMBtu/hr (HHV) Gas 2,819 2,538

MMBtu/hr (HHV) Oil 2,334 2,453

HRSG Velocity ft/sec Gas 57.3 58.2

ft/sec Oil 70.9 72.8

HRSG Temperature oF Gas 195 195

oF Oil 355 355

HRSG Stack Height feet Gas/Oil 149 149HRSG Stack Diameter feet Gas/Oil 22 22

1

1

2

2

3

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Fig 2-2.vsd

333

January 2012
January 2012 

Figure 2-3. Comparison of Historical Actual SO2, NOx, and PM Annual Emissions (TPY) for the Existing Units 1 through 4 at Port Everglades Plant Com

Potential Annual Emissions (TPY) for PEEC 

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Figure 2-3rev1.docx Source: Golder, 2012. 

0

1,0002,0003,0004,0005,0006,0007,0008,0009,000

10,000

SO2 NOx PM

9,494

4,260

604

211 382 24

(tons/year)

Existing Port Everglades Plant (Units 1 through 4) PEEC (3-on-1)

Notes: Existing Port Everglades based on 2006 and 2007 with an approximate capacity factor of 29%.

PEEC based on 100% capacity factor on natural gas and light oil; 7,760 hours on gas and 1,000 hours of oil at full load.
January 2012 

Figure 2-4. Comparison of CO2 Emission Rates (lb/MW-hr) for the Existing Units 1 through 4 at Port Everglades Plant and PEECY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Figure 2-4rev1.docx Source: Golder, 2012. 

0

200400600800

1,0001,2001,4001,6001,800

Existing Port Everglades Plant

(Units 1 through 4)

PEEC (3-on-1)

1,738

795

(lb/MWh)

Notes: Existing Port Everglades based on 2007 eGrid Data from EPA (2010).

PEEC based on 100% capacity factor on natural gas and light oil; 7,760 hours on gas and 1,000 hours of oil at full load.


January 2012 

1300

260

60

604

221

32.4

98.5

24.2 3.0

0

200400600800

100012001400

3-Hour 24-Hour Annual

Concentration (ug/m

3

)

Total Air Quality SO2 Impacts Predicted for the 

Existing Units 1 through 4 at Port Everglades Plant and PEEC 

AAQS Existing Units 1-4 PEEC

PEEC

Impact

PEEC

Impact PEEC Impact

150

50 55.8

53.9

0

20406080

100120140160180200

24-Hour 

Concentration (ug/m

3

)

Total Air Quality PM10 Impacts Pre

Existing Units 1 through 4 at Port Evergla

AAQS Existing Units 1-4 

PEEC

Impact

100

80

100120

ug/m

3

)

Total Air Quality NO2 Impacts Predicted for the 

Existing Units 1 through 4 Port Everglades Plant and PEEC

PEEC

Impact

40,000

25,00030,00035,00040,00045,000

 (ug/m

3

)

Total Air Quality CO Impacts Predi

Existing Units 1 through 4 Port Everglade

PEEC

Impact 

21.1

13.3

0

204060

Annual

Concentration (u

AAQS Existing Units 1-4 PEEC

10,00

3,203 

3,220 

0

5,000

10,00015,00020,000

1-Hour 

Concentration

AAQS Existing Units 1-4 

Figure 6-1.Maximum Total Air Quality Impacts of the Existing Units 1 through 4 at Port Everglades and PEEC Compared to Ambient Air Quality StandardsPEEC/Appendix 10.2.5Source: Golder, 2011.

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Fig 6-1 PEECrev1.xlsx
APPENDIX A 

 
January 2012 113-87618

 CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,733.1 2,623.8 2,539.4 2,440.1

 (MMBtu/hr, HHV) 3,033.7 2,912.4 2,818.7 2,708.5

 Evaporative Cooler Off On On On

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,243 23,243 23,243 23,243

 (HHV/LHV) 1.110 1.110 1.110 1.110

Steam Flow (lb/hr) NA NA NA NA

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 4,949,000 4,768,200 4,625,400 4,441,300

 Temperature (°F) 1,159 1,173 1,188 1,202

 Moisture (% Vol.) 9.09 9.83 10.57 12.11

 Oxygen (% Vol.) 11.14 11.03 10.92 10.65

 Molecular Weight 28.42 28.33 28.25 28.12

 Volume flow (acfm) 3,437,425 3,351,097 3,289,887 3,200,507

 

Fuel Usage

Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,733 2,624 2,539 2,440

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 130,521 125,301 121,270 116,528

 

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 2,977,233 2,858,170 2,766,231 2,658,061

2.42E+10

Fuel Usage - Duct Burner Only

 Fuel usage (lb/hr)- calculated 0000

 Fuel usage (cf/hr)- calculated 0000

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 4,949,000 4,768,200 4,625,400 4,441,300

 HRSG Stack Temperature (o

F) 196 195 195 195

 Molecular weight 28.42 28.33 28.25 28.12

 Volume flow (acfm) 1,392,804 1,344,133 1,307,570 1,261,331

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec)- calculated 61.1 58.9 57.3 55.3

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

TABLE A-1-501J

DESIGN INFORMATION AND STACK PARAMETERS FOR THE PEEC PROJECT

DRY LOW NOx COMBUSTOR, NATURAL GAS, BASE LOAD

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A1-G100 
January 2012 113-87618

CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr)

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m 3 /(3.283 ft) 3 ) x (273.15 K/ CT T

 Emission (mg/m3 N) 1 1 1 19

 Turbine Flow (acfm) 3,437,425 3,351,097 3,289,887 3,200,507 0

 (m 3

/hr) 5,844,709 5,697,925 5,593,849 5,441,874 0

 Temperature (°F) 1,159 1,173 1,188 1,202 0

 (K) 899 907 915 923 #

 Emission (lb/hr) 3.91 3.78 3.68 3.55 

 

 Total CT/DB emission rate (lb/hr) 3.9 3.8 3.7 3.5

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (=

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb 

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 17.0 16.3 15.8 15.2

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 DB SO2 emission rate (lb/hr) -- -- -- --

 Conversion (%) from SO2 to SO3 in DB -- -- -- --

 Remaining SO2 (lb/hr) after conversion 15.3 14.7 14.2 13.7

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 4.46 4.28 4.14 3.98

 Total HRSG stack emission rate (lb/hr) [a + b] 8.4 8.1 7.8 7.5 #

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 2,977,233 2,858,170 2,766,231 2,658,061

 Sulfur content (grains/ 100 cf) 2222

 lb SO2 /lb S (64/32) 2222

 HRSG stack emission rate (lb/hr) 17.0 16.3 15.8 15.2

 

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppmv actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas con

 Basis, ppm actual 46.6 46.4 46.1 45.8

 CT/DB, ppmvd @15% O2 35 35 35 35

 Moisture (%) 9.09 9.83 10.57 12.11

 Oxygen (%) 11.14 11.03 10.92 10.65

 Oxygen (%) dry 12.25 12.23 12.21 12.12

 Turbine Flow (acfm) 3,437,425 3,351,097 3,289,887 3,200,507

 Turbine Flow (acfm), dry 3,125,088 3,021,748 2,942,189 2,812,858

 Turbine Exhaust Temperature (°F) 1,159 1,173 1,188 1,202

 CT/DB emission rate (lb/hr) 373.7 358.9 347.2 332.6

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG stack emission rate (lb/hr) 21.4 20.5 19.8 19.0 #

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constan

 Basis, ppm actual 12.00 11.92 11.85 11.77

 Basis, ppmvd @ 15% O2 9.00 9.00 9.00 9.00

 Moisture (%) 9.09 9.83 10.57 12.11

 Oxygen (%) 11.14 11.03 10.92 10.65 

 Oxygen (%) dry 12.25 12.23 12.21 12.12 

 Turbine Flow (acfm) 3,437,425 3,351,097 3,289,887 3,200,507 

 Turbine Flow (acfm), dry 3,125,088 3,021,748 2,942,189 2,812,858 

 Turbine Exhaust Temperature (°F) 1,159 1,173 1,188 1,202 

 CT/DB emission rate (lb/hr) 58.5 56.2 54.3 52.1

 HRSG Stack emission rate, ppmvd @ 15% O2 9.0 9.0 9.0 9.0

 HRSG Stack emission rate (lb/hr) 58.5 56.2 54.3 52.1 

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas con

 Basis, ppm actual 1.33 1.32 1.32 1.31

 Basis, ppmvd @ 15% O2 1.00 1.00 1.00 1.00

 Moisture (%) 9.09 9.83 10.57 12.11 

 Oxygen (%) wet 11.14 11.03 10.92 10.65 

 Oxygen (%) dry 12.25 12.23 12.21 12.12 

 Turbine Flow (acfm) 3,437,425 3,351,097 3,289,887 3,200,507 

 Turbine Flow (acfm), dry 3,125,088 3,021,748 2,942,189 2,812,858 

 Turbine Exhaust Temperature (°F) 1,159 1,173 1,188 1,202 

 CT/DB emission rate (lb/hr) 3.71 3.57 3.45 3.31

 HRSG Stack emission rate, ppmvd @ 15% O2 1.0 1.0 1.0 1.0

 HRSG Stack emission rate (lb/hr) 3.7 3.6 3.5 3.3 

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 17.0 16.3 15.8 15.2

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 (lb/hr)(remaining SO2 after conversion) 15.3 14.7 14.2 13.7

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 3.31 3.18 3.07 2.95

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 Emission rate (lb/hr) NA NA NA NA

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: MPS, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

TABLE A-2-501J

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, BASE LOAD

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A2-G100
January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,202.7 2,090.4 2,017.4 1,930.2

 (MMBtu/hr, HHV) 2,445.0 2,320.3 2,239.3 2,142.5

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,243 23,243 23,243 23,243

 (HHV/LHV) 1.110 1.110 1.110 1.110

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass flow (lb/hr) 4,064,000 3,889,000 3,764,200 3,606,000

 Temperature (°F) 1,182 1,202 1,218 1,237

 Moisture (% Vol.) 8.86 9.34 10.04 11.49

 Oxygen (% Vol.) 11.41 11.39 11.32 11.06

 Molecular Weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 2,860,818 2,776,342 2,713,211 2,645,766

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,203 2,090 2,017 1,930

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 105,191 99,828 96,342 92,178

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 2,399,455 2,277,124 2,197,603 2,102,614

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 4,064,000 3,889,000 3,764,200 3,606,000

 HRSG Stack Temperature (o

F) 184 185 186 187

 Molecular weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 1,122,026 1,077,461 1,044,538 1,008,727

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 49.2 47.2 45.8 44.2

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

MPS 501J CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 75% LOAD

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

TABLE A-3-501J

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A3-G75
January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr)

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m 3 /(3.283 ft) 3 ) x (273.15 K/ CT Temp (K)) x 2.2046 x 10 -6 lb/mg

 Emission (mg/m3 N) 11 1 1

 Turbine Flow (acfm) 2,860,818 2,776,342 2,713,211 2,645,766

 (m 3

/hr) 4,864,295 4,720,660 4,613,317 4,498,639

 Temperature (°F) 1,182 1,202 1,218 1,237

 (K) 912 923 932 943

 Emission (lb/hr) 3.21 3.08 2.98 2.87

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 13.7 13.0 12.6 12.0

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 12.3 11.7 11.3 10.8

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 3.59 3.41 3.29 3.15

 Total HRSG stack emission rate (lb/hr) [a + b] 6.8 6.5 6.3 6.0

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 2,399,455 2,277,124 2,197,603 2,102,614

 Sulfur content (grains/ 100 cf) 2 2 2 2

 lb SO2 /lb S (64/32) 22 2 2

 HRSG Stack emission rate (lb/hr) 13.7 13.0 12.6 12.0

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppm actual 45.3 44.8 44.4 44.1

 CT / DB, ppmvd @15% O2 35 35 35 35

 Moisture (%) 8.86 9.34 10.04 11.49

 Oxygen (%) 11.41 11.39 11.32 11.06

 Oxygen (%) dry 12.52 12.56 12.58 12.50

 Turbine Flow (acfm) 2,860,818 2,776,342 2,713,211 2,645,766

 Turbine Flow (acfm), dry 2,607,465 2,516,948 2,440,907 2,341,790

 Turbine Exhaust Temperature (°F) 1,182 1,202 1,218 1,237

 CT Emission rate (lb/hr) 297.8 282.6 270.8 259.6

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG Stack emission rate (lb/hr) 17.0 16.1 15.5 14.8

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 m

 Basis, ppm actual 11.6 11.5 11.4 11.3

 Basis, ppmvd @ 15% O2 99 9 9

 Moisture (%) 8.86 9.34 10.04 11.49

 Oxygen (%) 11.41 11.39 11.32 11.06

 Oxygen (%) dry 12.52 12.56 12.58 12.50

 Turbine Flow (acfm) 2,860,818 2,776,342 2,713,211 2,645,766

 Turbine Flow (acfm), dry 2,607,465 2,516,948 2,440,907 2,341,790

 Turbine Exhaust Temperature (°F) 1,182 1,202 1,218 1,237

 CT Emission rate (lb/hr) 46.6 44.2 42.4 40.6

 HRSG Stack emission rate, ppmvd @ 15% O2 99 9 9

 HRSG Stack emission rate (lb/hr) 46.6 44.2 42.4 40.6

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppmvd 1.29 1.28 1.27 1.26

 Basis, ppmvd @ 15% O2 11 1 1

 Moisture (%) 8.86 9.34 10.04 11.49

 Oxygen (%) 11.41 11.39 11.32 11.06

 Oxygen (%) dry 12.52 12.56 12.58 12.50

 Turbine Flow (acfm) 2,860,818 2,776,342 2,713,211 2,645,766

 Turbine Flow (acfm), dry 2,607,465 2,516,948 2,440,907 2,341,790

 Turbine Exhaust Temperature (°F) 1,182 1,202 1,218 1,237

 CT Emission rate (lb/hr) 2.96 2.81 2.69 2.58

 

 HRSG Stack emission rate, ppmvd @ 15% O2 11 1 1

 HRSG Stack emission rate (lb/hr) 3.0 2.8 2.7 2.6

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 13.7 13.0 12.6 12.0

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 00 0 0

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after 12.3 11.7 11.3 10.8

 conversion)

 HRSG Stack emission rate (lb/hr) 2.67 2.53 2.44 2.34

 

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 HRSG Stack emission rate (lb/hr) NA NA NA NA

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: MPS, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

MPS 501J CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 75% LOAD

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

TABLE A-4-501J

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A4-G75
January 2012 113-87618

 

 

Parameter 35 °F 59 °F 75 °F 95 °F

 

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 1,673.7 1,594.0 1,540.8 1,476

 (MMBtu/hr, HHV) 1,857.8 1,769.3 1,710.3 1,638.5

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,243 23,243 23,243 23,243

 (HHV/LHV) 1.110 1.110 1.110 1.110

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass flow (lb/hr) 3,197,900 3,125,400 3,070,200 2,991,800

 Temperature (°F) 1,237 1,237 1,237 1,237

 Moisture (% Vol.) 8.56 8.92 9.50 10.85

 Oxygen (% Vol.) 11.72 11.86 11.90 11.77

 Molecular Weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 1,674 1,594 1,541 1,476

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 79,928 76,122 73,582 70,492

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 1,823,203 1,736,383 1,678,431 1,607,952

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 3,197,900 3,125,400 3,070,200 2,991,800

 HRSG Stack Temperature (o

F) 184 185 186 187

 Molecular weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 882,905 865,903 851,958 836,914

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 38.7 38.0 37.4 36.7

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-5-501J

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 50% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A5-G50
January 2012 113-87618

 

Parameter 35 °F 59 °F 75 °F 95 °F

 

Particulate from CT and HRSG

Particulate (including PM2.5) from CT and SCR

 a. PM10 (front half) (lb/hr)

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m3 /(3.283 ft) 3 ) x (273.15 K/ CT Temp (K)) x 2.2046 x 10 -6 lb/mg)

 Emission (mg/m3

 N) 11 1 1

 Turbine Flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120

 (m3

/hr) 3,955,850 3,873,657 3,805,374 3,732,398

 Temperature (°F) 1,237 1,237 1,237 1,237

 (K) 943 943 943 943

 Emission (lb/hr) 2.53 2.47 2.43 2.38

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 10.4 9.9 9.6 9.2

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 9.4 8.9 8.6 8.3

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 2.73 2.60 2.51 2.41

 Total HRSG stack emission rate (lb/hr) [a + b] 5.3 5.1 4.9 4.8

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 1,823,203 1,736,383 1,678,431 1,607,952

 Sulfur content (grains/ 100 cf) 2 2 2 2

 lb SO2 /lb S (64/32) 2 2 2 2

 HRSG Stack emission rate (lb/hr) 10.4 9.9 9.6 9.2

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60

 Basis, ppm actual 43.8 42.6 41.6 40.7

 CT / DB, ppmvd @15% O2 35 35 35 35

 Moisture (%) 8.56 8.92 9.50 10.85

 Oxygen (%) 11.72 11.86 11.90 11.77

 Oxygen (%) dry 12.82 13.02 13.14 13.20

 Turbine Flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120

 Turbine Flow (acfm), dry 2,127,478 2,075,037 2,025,412 1,957,007

 Turbine Exhaust Temperature (°F) 1,237 1,237 1,237 1,237

 CT Emission rate (lb/hr) 226.7 215.6 207.2 198.8

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG Stack emission rate (lb/hr) 13.0 12.3 11.8 11.4

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min

 Basis, ppm actual 11.3 10.9 10.7 10.5

 Basis, ppmvd @ 15% O2 99 9 9

 Moisture (%) 8.56 8.92 9.50 10.85

 Oxygen (%) 11.72 11.86 11.90 11.77

 Oxygen (%) dry 12.82 13.02 13.14 13.20

 Turbine Flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120

 Turbine Flow (acfm), dry 2,127,478 2,075,037 2,025,412 1,957,007

 Turbine Exhaust Temperature (°F) 1,237 1,237 1,237 1,237

 CT Emission rate (lb/hr) 35.5 33.7 32.4 31.1

 HRSG Stack emission rate, ppmvd @ 15% O2 99 9 9

 HRSG Stack emission rate (lb/hr) 35.5 33.7 32.4 31.1

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60

 Basis, ppmvd 1.25 1.22 1.19 1.16

 Basis, ppmvd @ 15% O2 11 1 1

 Moisture (%) 8.56 8.92 9.50 10.85

 Oxygen (%) 11.72 11.86 11.90 11.77

 Oxygen (%) dry 12.82 13.02 13.14 13.20

 Turbine Flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120

 Turbine Flow (acfm), dry 2,127,478 2,075,037 2,025,412 1,957,007

 Turbine Exhaust Temperature (°F) 1,237 1,237 1,237 1,237

 CT Emission rate (lb/hr) 2.25 2.14 2.06 1.98

 HRSG Stack emission rate, ppmvd @ 15% O2 11 1 1

 HRSG Stack emission rate (lb/hr) 2.3 2.1 2.1 2.0

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 10.4 9.9 9.6 9.2

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0 0 0 0

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conv 9.4 8.9 8.6 8.3

 SCR Conversion to H2SO4 (% by weight) 3 3 3 3

 HRSG Stack emission rate (lb/hr) 2.03 1.93 1.87 1.79

 

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 HRSG Stack emission rate (lb/hr) NA NA NA NA

 

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-6-501J

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 50% LOAD

Turbine Inlet Temperature

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,436.6 2,292.1 2,201.5 2,096.5

 (MMBtu/hr, HHV) 2,582.8 2,429.6 2,333.6 2,222.3

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,490 19,490 19,490 19,490

 (HHV/LHV) 1.060 1.060 1.060 1.060

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 5,050,000 4,799,000 4,639,600 4,436,700

 Temperature (°F) 982 1,000 1,014 1,033

 Moisture (% Vol.) 8.22 8.70 9.32 10.77

 Oxygen (% Vol.) 12.06 12.08 12.00 11.79

 Molecular Weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 3,097,943 2,986,968 2,923,623 2,842,769

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,437 2,292 2,202 2,097

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 132,518 124,659 119,731 114,021

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 5,050,000 4,799,000 4,639,600 4,436,700

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 1,759,511 1,671,474 1,616,522 1,549,909

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 77.1 73.3 70.9 68.0

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

TABLE A-7-501J

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A7-O100
January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m 3 /(3.283 ft) 3 ) x (273.15 K/ CT Temp (K)) x 2.2046 x 10 -6 lb/mg)

 Emission (mg/m3

 N) 5555

 Turbine Flow (acfm) 3,097,943 2,986,968 2,923,623 2,842,769

 (m 3

/hr) 5,267,483 5,078,790 4,971,085 4,833,607

 Temperature (°F) 982 1,000 1,014 1,033

 (K) 801 811 819 829

 Emission (lb/hr) 19.80 18.86 18.28 17.55

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 4.0 3.7 3.6 3.4

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 3.6 3.4 3.2 3.1

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 1.04 0.98 0.94 0.90

 Total HRSG stack emission rate (lb/hr) [a + b] 20.8 19.8 19.2 18.4

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 132,518 124,659 119,731 114,021

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 4.0 3.7 3.6 3.4

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 50.7 49.9 49.5 48.8

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 8.22 8.70 9.32 10.77

 Oxygen (%) 12.06 12.08 12.00 11.79

 Oxygen (%) dry 13.15 13.23 13.23 13.21

 Turbine Flow (acfm) 3,097,943 2,986,968 2,923,623 2,842,769

 Turbine Flow (acfm), dry 2,843,152 2,727,119 2,651,021 2,536,589

 Turbine Exhaust Temperature (°F) 982 1,000 1,014 1,033

 CT Emission rate (lb/hr) - calculated 410.6 385.0 370.5 350.7

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) 78.2 73.3 70.6 66.8

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 42.2 41.6 41.3 40.7

 Basis, ppmvd @ 15% O2 35 35 35 35

 Moisture (%) 8.22 8.70 9.32 10.77

 Oxygen (%) 12.06 12.08 12.00 11.79

 Oxygen (%) dry 13.15 13.23 13.23 13.21

 Turbine Flow (acfm) 3,097,943 2,986,968 2,923,623 2,842,769

 Turbine Flow (acfm), dry 2,843,152 2,727,119 2,651,021 2,536,589

 Turbine Exhaust Temperature (°F) 982 1,000 1,014 1,033

 CT Emission rate (lb/hr) 208.3 195.3 187.9 177.9

 HRSG Stack emission rate, ppmvd @ 15% O2 35.0 35.0 35.0 35.0

 HRSG Stack emission rate (lb/hr) 208.3 195.3 187.9 177.9

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 12.1 11.9 11.8 11.6

 Basis, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 Moisture (%) 8.22 8.70 9.32 10.77

 Oxygen (%) 12.06 12.08 12.00 11.79

 Oxygen (%-dry) 13.15 13.23 13.23 13.21

 Turbine Flow (acfm) 3,097,943 2,986,968 2,923,623 2,842,769

 Turbine Flow (acfm), dry 2,843,152 2,727,119 2,651,021 2,536,589

 Turbine Exhaust Temperature (°F) 982 1,000 1,014 1,033

 CT Emission rate (lb/hr) 34.0 31.9 30.7 29.0

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) 34.0 31.9 30.7 29.0

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 4.0 3.7 3.6 3.4

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversio 3.6 3.4 3.2 3.1

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.77 0.73 0.70 0.67

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr)- calculated 0.0362 0.0340 0.0327 0.0311

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

TABLE A-8-501J

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January 2012 113-87618

 

 

Parameter 35 °F 59 °F 75 °F 95 °F

 

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 1,987.1 1,877.5 1,806.9 1,723.2

 (MMBtu/hr, HHV) 2,106.3 1,990.2 1,915.3 1,826.6

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,490 19,490 19,490 19,490

 (HHV/LHV) 1.060 1.060 1.060 1.060

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 4,117,900 3,931,700 3,800,500 3,626,200

 Temperature (°F) 1,034 1,054 1,069 1,091

 Moisture (% Vol.) 8.19 8.67 9.32 10.79

 Oxygen (% Vol.) 12.11 12.09 12.01 11.76

 Molecular Weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 1,987 1,878 1,807 1,723

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 108,071 102,110 98,271 93,718

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 4,117,900 3,931,700 3,800,500 3,626,200

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 1,434,751 1,369,397 1,324,164 1,266,770

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 62.9 60.0 58.1 55.5

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-9-501J

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 75% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A9-O75
January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m3 /(3.283 ft) 3 ) x (273.15 K/ CT Temp (K)) x 2.2046 x 10 -6 lb/mg)

 Emission (mg/m3

 N) 5555

 Turbine Flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711

 (m3

/hr) 4,450,132 4,314,822 4,223,975 4,104,072

 Temperature (°F) 1,034 1,054 1,069 1,091

 (K) 830 841 849 861

 Emission (lb/hr) 16.15 15.45 14.98 14.34

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 3.2 3.1 2.9 2.8

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 2.9 2.8 2.7 2.5

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 0.85 0.80 0.77 0.74

 Total HRSG stack emission rate (lb/hr) [a + b] 17.0 16.3 15.7 15.1

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 108,071 102,110 98,271 93,718

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 3.2 3.1 2.9 2.8

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 50.4 49.8 49.4 49.0

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 8.19 8.67 9.32 10.79

 Oxygen (%) 12.11 12.09 12.01 11.76

 Oxygen (%) dry 13.19 13.24 13.24 13.19

 Turbine Flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711

 Turbine Flow (acfm), dry 2,402,815 2,317,703 2,252,597 2,153,362

 Turbine Exhaust Temperature (°F) 1,034 1,054 1,069 1,091

 CT Emission rate (lb/hr) 333.0 314.9 303.1 287.6

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) 63.4 60.0 57.7 54.8

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 42.0 41.5 41.2 40.8

 Basis, ppmvd @ 15% O2 35 35 35 35

 Moisture (%) 8.19 8.67 9.32 10.79

 Oxygen (%) 12.11 12.09 12.01 11.76

 Oxygen (%) dry 13.19 13.24 13.24 13.19

 Turbine Flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711

 Turbine Flow (acfm), dry 2,402,815 2,317,703 2,252,597 2,153,362

 Turbine Exhaust Temperature (°F) 1,034 1,054 1,069 1,091

 CT Emission rate (lb/hr) 168.9 159.7 153.7 145.9

 HRSG Stack emission rate, ppmvd @ 15% O2 35.0 35.0 35.0 35.0

 HRSG Stack emission rate (lb/hr) 168.9 159.7 153.7 145.9

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 12.0 11.9 11.8 11.7

 Basis, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 Moisture (%) 8.19 8.67 9.32 10.79

 Oxygen (%) 12.11 12.09 12.01 11.76

 Oxygen (%-dry) 13.19 13.24 13.24 13.19

 Turbine Flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711

 Turbine Flow (acfm), dry 2,402,815 2,317,703 2,252,597 2,153,362

 Turbine Exhaust Temperature (°F) 1,034 1,054 1,069 1,091

 CT Emission rate (lb/hr) 27.6 26.1 25.1 23.8

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) 27.6 26.1 25.1 23.8

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 3.2 3.1 2.9 2.8

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversion) 2.9 2.8 2.7 2.5

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.63 0.60 0.57 0.55

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr) 0.0295 0.0279 0.0268 0.0256

 

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-10-501J

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 75% LOAD

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 1,723.0 1,634.1 1,576.3 1,507.2

 (MMBtu/hr, HHV) 1,826.4 1,732.1 1,670.9 1,597.6

 Relative Humidity (%) 60 60 60 60

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,490 19,490 19,490 19,490

 (HHV/LHV) 1.060 1.060 1.060 1.060

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 3,514,800 3,369,200 3,264,800 3,124,000

 Temperature (°F) 1,099 1,118 1,133 1,153

 Moisture (% Vol.) 8.32 8.79 9.43 10.90

 Oxygen (% Vol.) 11.97 11.97 11.88 11.64

 Molecular Weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 1,723 1,634 1,576 1,507

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 93,708 88,873 85,729 81,971

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 3,514,800 3,369,200 3,264,800 3,124,000

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 1,224,620 1,173,480 1,137,516 1,091,333

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 53.7 51.5 49.9 47.8

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-11-501J

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 50% LOAD

Turbine Inlet Temperature

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January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 Particulate from CT (lbhr)= Emission (mg/m 3 N) x Flow rate (acfm) x 60 min/hr x (1 m3 /(3.283 ft) 3 ) x (273.15 K/ CT Temp (K)) x 2.2046 x 10 -6 lb/mg)

 Emission (mg/m3

 N) 5555

 Turbine Flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555

 (m3

/hr) 3,963,631 3,853,811 3,780,467 3,677,027

 Temperature (°F) 1,099 1,118 1,133 1,153

 (K) 866 876 885 896

 Emission (lb/hr) 13.78 13.24 12.86 12.36

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 2.8 2.7 2.6 2.5

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 2.5 2.4 2.3 2.2

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 0.74 0.70 0.67 0.64

 Total HRSG stack emission rate (lb/hr) [a + b] 14.5 13.9 13.5 13.0

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 93,708 88,873 85,729 81,971

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 2.8 2.7 2.6 2.5

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 51.2 50.5 50.2 49.7

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 8.32 8.79 9.43 10.90

 Oxygen (%) 11.97 11.97 11.88 11.64

 Oxygen (%) dry 13.06 13.12 13.12 13.06

 Turbine Flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555

 Turbine Flow (acfm), dry 2,137,166 2,067,193 2,013,615 1,926,909

 Turbine Exhaust Temperature (°F) 1,099 1,118 1,133 1,153

 CT Emission rate (lb/hr) - calculated 288.6 273.7 264.2 251.4

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) 55.0 52.1 50.3 47.9

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 42.6 42.1 41.8 41.4

 Basis, ppmvd @ 15% O2 35 35 35 35

 Moisture (%) 8.32 8.79 9.43 10.90

 Oxygen (%) 11.97 11.97 11.88 11.64

 Oxygen (%) dry 13.06 13.12 13.12 13.06

 Turbine Flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555

 Turbine Flow (acfm), dry 2,137,166 2,067,193 2,013,615 1,926,909

 Turbine Exhaust Temperature (°F) 1,099 1,118 1,133 1,153

 CT Emission rate (lb/hr) 146.4 138.8 134.0 127.5

 HRSG Stack emission rate, ppmvd @ 15% O2 35.0 35.0 35.0 35.0

 HRSG Stack emission rate (lb/hr) 146.4 138.8 134.0 127.5

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 12.2 12.0 11.9 11.8

 Basis, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 Moisture (%) 8.32 8.79 9.43 10.90

 Oxygen (%) 11.97 11.97 11.88 11.64

 Oxygen (%-dry) 13.06 13.12 13.12 13.06

 Turbine Flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555

 Turbine Flow (acfm), dry 2,137,166 2,067,193 2,013,615 1,926,909

 Turbine Exhaust Temperature (°F) 1,099 1,118 1,133 1,153

 CT Emission rate (lb/hr) 23.9 22.7 21.9 20.8

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) 23.9 22.7 21.9 20.8

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 2.8 2.7 2.6 2.5

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversion) 2.5 2.4 2.3 2.2

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.55 0.52 0.50 0.48

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr)- calculated 0.0256 0.0243 0.0234 0.0224

 

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-12 501J

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 50% LOAD

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January 2012 113-87618

Emission Rate (lb/hr) 

Parameter firing Natural Gas Maximum Annual

 - Base Load a Emission (TPY) b

Ambient Temperature (oF): 75 °F 1 3

HIR (MMBtu/hr): 2,819 CT/HRSG CTs/HRSGs

Sulfuric acid mist 2.10 9.2 27.6

HAPs [Section 112(b) of Clean Air Act]

1,3-Butadiene 0.001212 0.005 0.016

Acetaldehyde 0.1127 0.49 1.48

Acrolein 0.0180 0.08 0.24

Benzene 0.0338 0.15 0.44

Ethylbenzene 0.0902 0.40 1.19

Formaldehyde 0.610 2.67 8.02

Naphthalene 0.00366 0.02 0.05

Polycyclic Aromatic Hydrocarbons (PAH) c 0.00620 0.03 0.08

Propylene Oxide 0.0817 0.36 1.07

Toluene 0.0930 0.41 1.22

Xylene 0.180 0.79 2.37

Antimony 0.0 0.0 0.0

Arsenic 0.0 0.0 0.0

Beryllium 0.0 0.0 0.0

Cadmium 0.0 0.0 0.0

Chromium 0.0 0.0 0.0

Lead 0.0 0.0 0.0

Manganese 0.0 0.0 0.0

Mercury 0.0000028 0.0 0.000037

Nickel 0.0 0.0 0.0

Selenium 0.0 0.0 0.0

HAPs (Total) 1.231 5.39 16.2

a

 Emissions based on the following emission factors and conversion factors for firing natural gas:

Emission Factors Value Reference

Sulfuric acid mist 10 %; Conversion of SO2 to SO3 in gas turbine

1,3-Butadiene (a) 0.43 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Acetaldehyde 40 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Acrolein 6.4 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Benzene 12 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Ethylbenzene 32 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Formaldehyde 0.091 ppmvd @15% O2 (see Table 9a) 

Naphthalene 1.3 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Polycyclic Aromatic Hydrocarbons (PAH) 2.2 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Propylene Oxide (a) 29 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Toluene 33 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000. Database

Xylene 64 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Antimony 0.00E+00

Arsenic 0.00E+00

Beryllium 0.00E+00

Cadmium 0.00E+00

Chromium 0.00E+00

Lead 0.00E+00

Manganese 0.00E+00

Mercury 1.00E-03

Nickel 0.00E+00

Selenium 0.00E+00

 (a) Based on 1/2 the detection limit; expected emissions are lower.

b Annual emissions based on firing natural gas for : 8760 hours.

c

 Assumed to be representative of Polycyclic Organic Matter (POM) emissions, a regulated HAP.

TABLE A-13-501J

WHEN FIRING NATURAL GAS, MPS 501J CT

REGULATED AND HAZARDOUS AIR POLLUTANT EMISSION FACTORS AND EMISSIONS

FOR THE PEEC PROJECT

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

 

Formaldehyde (CH2O) MW = 30 

 CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2116.8 lb/ft 2 (pressure) / 

 [1545.7 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 CH 2 O (ppm actual) = CH 2 O (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x (1- Moisture(%)/100)

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 Basis, ppm actual- calculated 0.121 0.121 0.121 0.119

 CT, ppmvd @15% O2 0.091 0.091 0.091 0.091

 Moisture (%) 9.086353529 9.828102225 9.82 12.11211849

 Oxygen (%) 11.14 11.03 11.02 10.65

 Oxygen (%) dry 12.25 12.23 12.22 12.12

 Exhaust Flow (acfm) 1,392,804 1,344,133 1,324,878 1,261,331

 Exhaust Temperature (°F) 196 195 185 195

 CT Emission rate (lb/hr) 0.634 0.609 0.610 0.564

 CT Emission rate (lb/1012 Btu) (HHV) 208.9 209.0 209.5 208.2 

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-13a-501J

CT Only at Baseload

Turbine Inlet Temperature

WHEN FIRING NATURAL GAS, MPS 501J CT

MAXIMUM FORMALDEHYDE EMISSIONS

FOR THE PEEC PROJECT

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January 2012 113-87618

Emission Rate (lb/hr) Emission Rate (lb/hr)

Parameter Distillate Fuel Oil a Natural Gas b

1 CT/HRSG - Base Load 1 CT/HRSG - Base Load

Ambient Temperature (o

F): 75 °F 75 °F

HIR (MMBtu/hr): 2,334 2,819 500 1,000 1,500 500 1,000 1,500

Sulfuric acid mist 0.70 2.10 0.52 1.05 1.57 26.5 25.5 24.4

HAPs [Section 112(b) of Clean Air Act]

1,3-Butadiene 0.0373 0.0012 0.028 0.056 0.084 0.04 0.07 0.10

Acetaldehyde 0.00 0.113 0.00 0.00 0.00 1.40 1.31 1.23

Acrolein 0.00 0.018 0.00 0.00 0.00 0.22 0.21 0.20

Benzene 0.128 0.034 0.10 0.19 0.29 0.52 0.59 0.66

Ethylbenzene 0.00 0.090 0.00 0.00 0.00 1.12 1.05 0.98

Formaldehyde 0.544 0.610 0.41 0.82 1.22 7.97 7.92 7.87

Naphthalene 0.0817 0.004 0.06 0.12 0.18 0.11 0.17 0.22

Polycyclic Aromatic Hydrocarbons (PAH) c 0.0933 0.006 0.07 0.14 0.21 0.15 0.21 0.28

Propylene Oxide 0.00 0.082 0.00 0.00 0.00 1.01 0.95 0.89

Toluene 0.00 0.093 0.00 0.00 0.00 1.15 1.08 1.01

Xylene 0.00 0.180 0.00 0.00 0.00 2.24 2.10 1.96

Antimony 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Arsenic 0.0257 0.00 0.019 0.039 0.058 0.02 0.04 0.06

Beryllium 0.000723 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cadmium 0.01120 0.00 0.008 0.017 0.025 0.01 0.02 0.03

Chromium 0.0257 0.00 0.019 0.039 0.058 0.02 0.04 0.06

Lead 0.0327 0.00 0.025 0.049 0.074 0.02 0.05 0.07

Manganese 1.84 0.00 1.38 2.77 4.15 1.38 2.77 4.15

Mercury 0.00280 0.00 0.002 0.00420 0.006 0.00 0.00423 0.01

Nickel 0.01073 0.00 0.008 0.016 0.024 0.01 0.02 0.02

Selenium 0.0583 0.00 0.04 0.09 0.13 0.04 0.09 0.13

HAPs (Total) 2.90 1.2 2.17 4.34 6.52 17.4 18.7 19.9

a

 Emissions based on the following emission factors and conversion factors for firing distillate fuel oil:

Emission Factors Value Reference

Sulfuric acid mist 5 %; Conversion of SO2 to SO3 in gas turbine

1,3-Butadiene (a) 16 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Acetaldehyde 0.0 

Acrolein 0.0 

Benzene 55 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Ethylbenzene 0.0

Formaldehyde 0.091 ppmvd @15% O2 (see Table 10a) 

Naphthalene 35 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Polycyclic Aromatic Hydrocarbons (PAH) 40 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Propylene Oxide 0.0 

Toluene 0.0 

Xylene 0.0

 

Antimony 0.0 

Arsenic (a) 11 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Beryllium (a) 0.31 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Cadmium 4.8 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Chromium 11 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Lead 14 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Manganese 790 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Mercury 1.2 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Nickel (a) 4.6 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Selenium (a) 25 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

 (a) Based on 1/2 the detection limit; expected emissions are lower.

b

 Natural gas firing emission rates based on Table A-13.

c

 Assumed to be representative of Polycyclic Organic Matter (POM) emissions, a regulated HAP

3 CTs/HRSGs

TABLE A-14-501J

Maximum Annual Emissions (TPY)

REGULATED AND HAZARDOUS AIR POLLUTANT EMISSION FACTORS AND EMISSIONS FOR THE PEEC PROJECT

Maximum Annual Emissions (TPY)

3 CTs/HRSGs

- Hours on Distillate Fuel Oil Only

Natural Gas and Fuel Oil

- Hours on Distillate Fuel Oil

WHEN FIRING DISTILLATE FUEL OIL, MPS 501J CT

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Parameter 35 °F 59 °F 75 °F 95 °F 

Formaldehyde (CH2O) MW = 30

 CH 2 O (lb/hr) = CH2 O (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2116.8 lb/ft 2 (pressure) / 

 [1545.7 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 CH 2 O (ppm actual) = CH 2 O (ppmd @ 15%O 2 ) x [(20.9 - O2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 Basis, ppmvw - calculated 0.110 0.108 0.107 0.106

 CT, ppmvd @15% O2 0.091 0.091 0.091 0.091

 Moisture (%) 8.22 8.70 9.324120751 10.77047881

 Oxygen (%) 12.06 12.08 12.00 11.79

 Oxygen (%) dry 13.15 13.23 13.23 13.21

 Exhaust Flow (acfm) 1,759,511 1,671,474 1,616,522 1,549,909

 Exhaust Temperature (°F) 359 357 355 354

 CT Emission rate (lb/hr) 0.580 0.544 0.523 0.496

 CT Emission rate (lb/1012 Btu) (HHV) 224.6 223.9 224.3 223.0 

Note: ppmvd = parts per million, volume dry; O2 = oxygen.

Source: MPS, 2011; CT Performance Data; Golder, 2011.

TABLE A-14a-501G

CT Only

Turbine Inlet Temperature

MPS 501J CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

MAXIMUM FORMALDEHYDE EMISSIONS

FOR THE PEEC PROJECT

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January 2012 113-87618

Parameter Units Value Fire Pump Engine Emergency Generators 

Number 1 2

Heat Input Rate MMBtu/hr per unit 2.32 21.0

Maximum operation/yr hours per unit 100 100

Heat Input Rate/annual MMBtu/yr all units 232.0 4,202.0

HAPs [Section 112(b) of Clean Air Act]

Acrolein lb/MMBtu 7.88E-06 9.14E-07 1.66E-05 

Acetaldehyde lb/MMBtu 2.52E-05 2.92E-06 5.29E-05

Benzene lb/MMBtu 7.76E-04 9.00E-05 1.63E-03

Formaldehyde lb/MMBtu 7.89E-05 9.15E-06 1.66E-04

Naphthalene lb/MMBtu 1.30E-04 1.51E-05 2.73E-04

Toluene lb/MMBtu 2.81E-04 3.26E-05 5.90E-04

Xylene lb/MMBtu 1.93E-04 2.24E-05 4.05E-04

Acenaphthene lb/MMBtu 4.68E-06 5.43E-07 9.83E-06

Acenaphthylene lb/MMBtu 9.23E-06 1.07E-06 1.94E-05

Anthracene lb/MMBtu 1.23E-06 1.43E-07 2.58E-06

Benzo(a)anthracene lb/MMBtu 6.22E-07 7.22E-08 1.31E-06

Benzo(b)fluoranthene lb/MMBtu 1.11E-06 1.29E-07 2.33E-06

Benzo(k)fluoranthene lb/MMBtu 2.18E-07 2.53E-08 4.58E-07

Benzo(g,h,i)perylene lb/MMBtu 5.56E-07 6.45E-08 1.17E-06

Benzo(a)pyrene lb/MMBtu 2.57E-07 2.98E-08 5.40E-07

Chrysene lb/MMBtu 1.53E-06 1.77E-07 3.21E-06

Dibenzo(a,h)anthracene lb/MMBtu 3.46E-07 4.01E-08 7.27E-07

Fluoanthene lb/MMBtu 4.03E-06 4.67E-07 8.47E-06

Fluorene lb/MMBtu 4.47E-06 5.19E-07 9.39E-06

Indo(1,2,3-cd)pyrene lb/MMBtu 4.14E-07 4.80E-08 8.70E-07

Phenanthrene lb/MMBtu 1.05E-06 1.22E-07 2.21E-06

Pyrene lb/MMBtu 3.71E-06 4.30E-07 7.79E-06

 

Arsenic lb/1012 Btu 4.0 4.64E-07 8.40E-06

Beryllium lb/1012 Btu 3.0 3.48E-07 6.30E-06

Cadmium lb/1012 Btu 3.0 3.48E-07 6.30E-06

Chromium lb/1012 Btu 3.0 3.48E-07 6.30E-06

Lead lb/1012 Btu 9.0 1.04E-06 1.89E-05

Mercury lb/1012 Btu 3.0 3.48E-07 6.30E-06

Manganese lb/1012 Btu 6.0 6.96E-07 1.26E-05

Nickel lb/1012 Btu 3.0 3.48E-07 6.30E-06

Selenium lb/1012 Btu 15.0 1.74E-06 3.15E-05

HAPs (Total) 1.83E-04 3.31E-03

a

 EPA AP-42, Section 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines (October 1996)

b

 EPA AP-42, Section 1.3, Fuel Oil Combustion for metals (September 1998).

TABLE A-15

HAZARDOUS AIR POLLUTANT EMISSIONS

FOR ADDITIONAL PEEC EMISSION UNITS- OIL-FIRING

Annual Emission Basis

Emission Factor a, b Emissions (TPY)

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January 2012 113-87618

Parameter/Pollutant Units Value

Annual Emission 

Basis Units Value

Annual Emission 

Basis Units Value

Annual Emission 

Basis

Number 1 1 2

Heat Input Rate MMBtu/hr per unit 9.90 MMBtu/hr per unit 99.77 MMBtu/hr per unit 53.98

Fuel use scf/hr per unit 9,706 scf/hr per unit 97,814 scf/hr per unit NA

Maximum operation/yr hours per unit 8,760 hours per unit 2,000 hours per unit 8,760

Heat Input Rate/annual MMBtu/yr all units NA MMBtu/yr all units NA MMBtu/yr all units 945,760

Fuel use/annual MMscf/yr all units 85.02 MMscf/yr all units 195.63 MMscf/yr all units NA

HAPs [Section 112(b) of Clean Air Act] Emissions (TPY) Emissions (TPY) Emissions (TPY)

Benzene lb/106 scf 2.10E-03 8.93E-05 lb/106 scf 2.10E-03 2.05E-04 lb/1012 Btu 1.20E+01 5.67E-03

Formaldehyde lb/106 scf 7.50E-02 3.19E-03 lb/106 scf 7.50E-02 7.34E-03 lb/1012 Btu 7.10E+02 3.36E-01

Naphthalene lb/106 scf 6.10E-04 2.59E-05 lb/106 scf 6.10E-04 5.97E-05 lb/1012 Btu 1.30E+00 6.15E-04

Toluene lb/106 scf 3.40E-03 1.45E-04 lb/106 scf 3.40E-03 3.33E-04 lb/1012 Btu 3.30E+01 1.56E-02

Dichlorobenzene lb/106 scf 1.20E-03 5.10E-05 lb/106 scf 1.20E-03 1.17E-04 -- NA NA

Acenaphthene lb/106 scf 1.80E-06 7.65E-08 lb/106 scf 1.80E-06 1.76E-07 -- NA NA

Acenaphthylene lb/106 scf 1.80E-06 7.65E-08 lb/106 scf 1.80E-06 1.76E-07 -- NA NA

Acetaldehyde -- NA NA -- NA NA lb/1012 Btu 4.00E+01 1.89E-02

Acrolein -- NA NA -- NA NA lb/1012 Btu 6.40E+00 3.03E-03

Anthracene lb/106 scf 2.40E-06 1.02E-07 lb/106 scf 2.40E-06 2.35E-07 -- NA NA

Benzo(a)anthracene lb/106 scf 1.80E-06 7.65E-08 lb/106 scf 1.80E-06 1.76E-07 -- NA NA

Benzene lb/106 scf 2.10E-03 8.93E-05 lb/106 scf 2.10E-03 2.05E-04 lb/1012 Btu 1.20E+01 5.67E-03

Benzo(g,h,i)perylene lb/106 scf 1.20E-06 5.10E-08 lb/106 scf 1.20E-06 1.17E-07 -- NA NA

Chrysene lb/106 scf 1.80E-06 7.65E-08 lb/106 scf 1.80E-06 1.76E-07 -- NA NA

Dibenzo(a,h)anthracene lb/106 scf 1.20E-06 5.10E-08 lb/106 scf 1.20E-06 1.17E-07 -- NA NA

Ethylbenzene -- NA NA -- NA NA lb/1012 Btu 3.20E+01 1.51E-02

Fluoanthene lb/106 scf 3.00E-06 1.28E-07 lb/106 scf 3.00E-06 2.93E-07 -- NA NA

Fluorene lb/106 scf 2.80E-06 1.19E-07 lb/106 scf 2.80E-06 2.74E-07 -- NA NA

Indeno(1,2,3-cd)pyrene lb/106 scf 1.80E-06 7.65E-08 lb/106 scf 1.80E-06 1.76E-07 -- NA NA

Phenanthrene lb/106 scf 1.70E-05 7.23E-07 lb/106 scf 1.70E-05 1.66E-06 -- NA NA

Phenol -- NA NA -- NA NA -- NA NA

Pyrene lb/106 scf 5.00E-06 2.13E-07 lb/106 scf 5.00E-06 4.89E-07 -- NA NA

Xylene -- NA NA -- NA NA lb/1012 Btu 6.40E+01 3.03E-02

1,3-Butadiene -- NA NA -- NA NA lb/1012 Btu 4.30E-01 2.03E-04

Polycyclic Aromatic Hydrocarbons (PAH) -- NA NA -- NA NA lb/1012 Btu 2.20E+00 1.04E-03

Propylene Oxide -- NA NA -- NA NA lb/1012 Btu 2.90E+01 1.37E-02

Arsenic lb/106 scf 2.00E-04 8.50E-06 lb/106 scf 2.00E-04 1.96E-05 -- NA NA

Beryllium lb/106 scf 1.20E-05 5.10E-07 lb/106 scf 1.20E-05 1.17E-06 -- NA NA

Cadmium lb/106 scf 1.10E-03 4.68E-05 lb/106 scf 1.10E-03 1.08E-04 -- NA NA

Chromium lb/106 scf 1.40E-03 5.95E-05 lb/106 scf 1.40E-03 1.37E-04 -- NA NA

Cobalt lb/106 scf 8.40E-05 3.57E-06 lb/106 scf 8.40E-05 8.22E-06 -- NA NA

Mercury lb/106 scf 2.60E-04 1.11E-05 lb/106 scf 2.60E-04 2.54E-05 -- NA NA

Manganese lb/106 scf 3.80E-04 1.62E-05 lb/106 scf 3.80E-04 3.72E-05 -- NA NA

Nickel lb/106 scf 2.10E-03 8.93E-05 lb/106 scf 2.10E-03 2.05E-04 -- NA NA

Selenium lb/106 scf 2.40E-05 1.02E-06 lb/106 scf 2.40E-05 2.35E-06 -- NA NA

HAPs (Total) 3.83E-03 8.80E-03 0.45

a

 EPA AP-42, Section 1.4, Natural Gas Combustion (March 1998).

b

 EPA AP-42, Section 3.2, Stationary Gas Turbines (April 2000).

Emission Factor a Emission Factor b 

Auxillary Boiler

Emission Factor a 

TABLE A-16

HAZARDOUS AIR POLLUTANT EMISSIONS

FOR ADDITIONAL PEEC EMISSION UNITS- NATURAL GAS-FIRING

Fuel Heater Compressor Station

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A16 AddUnitsGas-HAP
January 2012 

Pollutant Natural Gas

Distillate Fuel 

Oil

Natural 

Gas

Distillate 

Fuel Oil Natural Gas

Distillate 

Fuel Oil

Natural 

Gas

Distillate 

Fuel Oil Natural Gas

Distillate 

Fuel Oil Natura

Natural Gas Only

CO2 2,818.7 0.0 116.9 163.0 329,386.2 0.0 8760 0 1,442,711.6 0 1,442,

CH4 2,818.7 0.0 0.002204 0.006612 6.2 0.0 8760 0 27.2 0 571

N2O 2,818.7 0.0 0.0002204 0.001322 0.6 0.0 8760 0 2.7 0 843

Total 1,444,

Natural Gas & Distillate Fuel Oil

CO2 2,818.7 2,333.6 116.9 163.0 329,386.2 380,393.5 7760 1000 1,278,018.5 190,196.7 1,278,

CH4 2,818.7 2,333.6 0.002204 0.006612 6.2125 15.4297 7760 1000 24.1 7.7 506

N2O 2,818.7 2,333.6 0.0002204 0.001322 0.6212 3.0859 7760 1000 2.4 1.5 747

Total 1,279,

Maximum Total 1,444,

a Table C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtu 

Pollutant Natural Gas Distillate Fuel Oil

CO2 53.02 73.96

CH4 0.001 0.003

N2O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH4 and N2O are multiplied by CO2e factor

Pollutant CO2e Factor

CH4 21

N2O 310

GREENHOUSE GAS (GHG) EMISSIONS

MPS 501J CT, DRY LOW NOx COMBUSTOR, BASE LOAD

TABLE A-17

Heat Input at 75 0F Emission Factor a Hourly GHG Emissions

 (MMBtu/hr) (lb/MMBtu) (lb/hr) Operating Hours (TPY)

Annual GHG Emissions 

Maximum

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January 2012 113-87618

Maximum Emission Hourly Annual CO2e 

Emission Unit/ Heat Input Factor a GHG Emissions Operating GHG Emissions Emissions Rate b 

Pollutant (MMBtu/hr) (lb/MMBtu) (lb/hr) Hours (TPY) (TPY)

Auxilliary Boiler (Natural Gas)

CO2 99.77 116.9 11,658.7 2,000 11,658.7 11,658.7

CH4 99.77 0.002204 0.220 2,000 0.220 4.618

N2O 99.77 0.0002204 0.0220 2,000 0.022 6.817

11,670.2

Emergency Generator (Fuel Oil)

CO2 21.01 163.0 3,424.8 200 342.5 342.5

CH4 21.01 0.006612 0.139 200 0.014 0.29

N2O 21.01 0.001322 0.028 200 0.0028 0.86

343.6

Natural Gas Heater (Natural Gas)

CO2 9.90 116.9 1,156.9 8,760 5,067.1 5067.1

CH4 9.90 0.002204 0.022 8,760 0.096 2.01

N2O 9.90 0.0002204 0.0022 8,760 0.0096 2.96

5,072.1

Fire Pump Engine (Fuel Oil)

CO2 2.32 163.0 378.2 80 15.1 15.1

CH4 2.32 0.006612 0.0153 80 0.00061 0.01

N2O 2.32 0.001322 0.0031 80 0.00012 0.04

15.2

 Gas Compressor (Natural Gas)

CO2 53.98 116.9 6,308.1 8,760 27,629.5 27,629.5

CH4 53.98 0.002204 0.119 8,760 0.521 10.94

N2O 53.98 0.0002204 0.012 8,760 0.0521 16.15

27,656.6

a Table C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtu 

Pollutant Natural Gas Distillate Fuel Oil

CO2 53.02 73.96

CH4 0.001 0.003

N2O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH4 and N2O are multiplied by CO2e factor

Pollutant CO2e Factor

CH4 21

N2O 310

TABLE A-18

GREENHOUSE GAS (GHG) EMISSIONS

FOR ADDITIONAL PEEC EMISSION UNITS

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A18 Other-GHG
ATTACHMENT 

 
TANKS 4.0.9d

Emissions Report - Summary Format 

Tank Indentification and Physical Characteristics

Identification

User Identification: 165,000 BBL - No. 2 Fuel Oil; PEEC

City: West Palm Beach

 State: Florida

Company: FPL

 Type of Tank: Vertical Fixed Roof Tank

Description: ULSD Oil

Tank Dimensions

Shell Height (ft): 36.40

Diameter (ft): 180.00

Liquid Height (ft) : 36.40

 Avg. Liquid Height (ft): 36.40

Volume (gallons): 6,930,000.00

 Turnovers: 8.37

Net Throughput(gal/yr): 58,000,000.00

Is Tank Heated (y/n): N

Paint Characteristics

Shell Color/Shade: Gray/Light

Shell Condition Good

 Roof Color/Shade: Gray/Light

Roof Condition: Good

Roof Characteristics

 Type: Dome

Height (ft) 0.00

Radius (ft) (Dome Roof) 90.00

Breather Vent Settings

Vacuum Settings (psig): -0.03

Pressure Settings (psig) 0.03

Meterological Data used in Emissions Calculations: Miami, Florida (Avg Atmospheric Pressure = 14.75 psia)

TANKS 4.0 Report Page 1

file://C:\AIRPROG\Tanks409d\summarydisplay.htm 1/13/2012
165,000 BBL - No. 2 Fuel Oil; PEEC - Vertical Fixed Roof Tank

West Palm Beach, Florida 

TANKS 4.0.9d

Emissions Report - Summary Format 

Liquid Contents of Storage Tank

Daily Liquid Surf. 

Temperature (deg F)

Liquid

Bulk

Temp Vapor Pressure (psia)

Vapor

Mol. 

Liquid

Mass 

Vapor

Mass Mol. Basis for Vapor Pressure

Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. Fract. Weight Calculations

Distillate fuel oil no. 2 All 83.70 75.41 92.00 78.13 0.0135 0.0106 0.0172 130.0000 188.00 Option 1: VP70 = .009 VP80 = .012

TANKS 4.0 Report Page 2

file://C:\AIRPROG\Tanks409d\summarydisplay.htm 1/13/2012
Emissions Report for: Annual 

165,000 BBL - No. 2 Fuel Oil; PEEC - Vertical Fixed Roof Tank

West Palm Beach, Florida 

TANKS 4.0.9d

Emissions Report - Summary Format 

Individual Tank Emission Totals

Losses(lbs)

Components Working Loss Breathing Loss Total Emissions

Distillate fuel oil no. 2 2,420.29 9,225.59 11,645.88

TANKS 4.0 Report Page 3

file://C:\AIRPROG\Tanks409d\summarydisplay.htm 1/13/2012
APPENDIX B 

 
January 2012 113-87618

 CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,503 2,389 2,291 2,193

 (MMBtu/hr, HHV) 2,774 2,648 2,539 2,431

 Evaporative Cooler Off On On On

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,208 23,208 23,208 23,208

 (HHV/LHV) 1.108 1.108 1.108 1.108

Steam Flow (lb/hr) NA NA NA NA

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 5,114,187 4,887,432 4,696,101 4,489,671

 Temperature (°F) 1,136 1,149 1,161 1,176

 Moisture (% Vol.) 13.08 14.25 15.38 17.11

 Oxygen (% Vol.) 10.63 10.48 10.35 10.11

 Molecular Weight 28.42 28.33 28.25 28.12

 Volume flow (acfm) 3,501,695 3,384,750 3,285,451 3,184,751

 

Fuel Usage

Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,503 2,389 2,291 2,193

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 119,532 114,088 109,408 104,728

 

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 2,726,580 2,602,397 2,495,643 2,388,889

2.19E+10

Fuel Usage - Duct Burner Only

 Fuel usage (lb/hr)- calculated 0000

 Fuel usage (cf/hr)- calculated 0000

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 5,114,187 4,887,432 4,696,101 4,489,671

 HRSG Stack Temperature (o

F) 196 195 195 195

 Molecular weight 28.42 28.33 28.25 28.12

 Volume flow (acfm) 1,439,293 1,377,881 1,327,557 1,275,068

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec)- calculated 63.1 60.4 58.2 55.9

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

DESIGN INFORMATION AND STACK PARAMETERS FOR THE PEEC PROJECT

TABLE B-1-SH

Turbine Inlet Temperature

SIEMENS H CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, BASE LOAD

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January 2012 113-87618

CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr)

 CT 11 10 10 9 9

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 11.0 10.0 10.0 9.0

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 15.6 14.9 14.3 13.7

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 DB SO2 emission rate (lb/hr) -- -- -- --

 Conversion (%) from SO2 to SO3 in DB -- -- -- --

 Remaining SO2 (lb/hr) after conversion 14.0 13.4 12.8 12.3

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 4.08 3.90 3.74 3.58

 Total HRSG stack emission rate (lb/hr) [a + b] 15.1 13.9 13.7 12.6 #

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 2,726,580 2,602,397 2,495,643 2,388,889

 Sulfur content (grains/ 100 cf) 2 2 2 2

 lb SO2 /lb S (64/32) 2 2 2 2

 HRSG stack emission rate (lb/hr) 15.6 14.9 14.3 13.7

 

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppmv actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 Basis, ppm actual 31.9 31.5 31.1 30.6

 CT/DB, ppmvd @15% O2 25 25 25 25

 Moisture (%) 13.08 14.25 15.38 17.11

 Oxygen (%) 10.63 10.48 10.35 10.11

 Oxygen (%) dry 12.23 12.22 12.23 12.20

 Turbine Flow (acfm) 3,501,695 3,384,750 3,285,451 3,184,751

 Turbine Flow (acfm), dry 3,043,764 2,902,531 2,780,062 2,639,942

 Turbine Exhaust Temperature (°F) 1,136 1,149 1,161 1,176

 CT/DB emission rate (lb/hr) 264.3 250.2 237.8 224.4

265 253 243 233

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG stack emission rate (lb/hr) (maximum) 21.2 20.2 19.4 18.6 

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 Basis, ppm actual 6.39 6.31 6.22 6.11

 Basis, ppmvd @ 15% O2 5.00 5.00 5.00 5.00

 Moisture (%) 13.08 14.25 15.38 17.11

 Oxygen (%) 10.63 10.48 10.35 10.11 

 Oxygen (%) dry 12.23 12.22 12.23 12.20 

 Turbine Flow (acfm) 3,501,695 3,384,750 3,285,451 3,184,751 

 Turbine Flow (acfm), dry 3,043,764 2,902,531 2,780,062 2,639,942 

 Turbine Exhaust Temperature (°F) 1,136 1,149 1,161 1,176 

 CT/DB emission rate (lb/hr) 32.2 30.5 28.9 27.3

32 31 30 28

 HRSG Stack emission rate, ppmvd @ 15% O2 5.0 5.0 5.0 5.0

 HRSG Stack emission rate (lb/hr) (maximum) 32.2 31.0 30.0 28.0 

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 Basis, ppm actual 1.28 1.26 1.24 1.22

 Basis, ppmvd @ 15% O2 1.00 1.00 1.00 1.00

 Moisture (%) 13.08 14.25 15.38 17.11 

 Oxygen (%) wet 10.63 10.48 10.35 10.11 

 Oxygen (%) dry 12.23 12.22 12.23 12.20 

 Turbine Flow (acfm) 3,501,695 3,384,750 3,285,451 3,184,751 

 Turbine Flow (acfm), dry 3,043,764 2,902,531 2,780,062 2,639,942 

 Turbine Exhaust Temperature (°F) 1,136 1,149 1,161 1,176 

 CT/DB emission rate (lb/hr) 3.68 3.48 3.31 3.12

3.7 3.5 3.4 3.2

 HRSG Stack emission rate, ppmvd @ 15% O2 1.0 1.0 1.0 1.0

 HRSG Stack emission rate (lb/hr) (maximum) 3.7 3.5 3.4 3.2 

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 15.6 14.9 14.3 13.7

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0 0 0 0

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 (lb/hr)(remaining SO2 after conversion) 14.0 13.4 12.8 12.3

 SCR Conversion to H2SO4 (% by weight) 3 3 3 3

 HRSG Stack emission rate (lb/hr) 3.03 2.89 2.77 2.65

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 Emission rate (lb/hr) NA NA NA NA

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / 

 [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

TABLE B-2-SH

Turbine Inlet Temperature

SIEMENS H CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, BASE LOAD

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / 

 [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2

 (pressure) / 

 [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,075 1,935 1,864 1,757

 (MMBtu/hr, HHV) 2,300 2,145 2,066 1,947

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,208 23,208 23,208 23,208

 (HHV/LHV) 1.108 1.108 1.108 1.108

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass flow (lb/hr) 4,219,577 3,998,317 3,927,207 3,762,809

 Temperature (°F) 1,165 1,172 1,177 1,185

 Moisture (% Vol.) 13.13 13.80 14.67 15.86

 Oxygen (% Vol.) 10.60 10.62 10.65 10.57

 Molecular Weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 2,939,582 2,802,860 2,761,508 2,676,221

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,075 1,935 1,864 1,757

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 99,093 92,407 89,016 83,906

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 2,260,349 2,107,843 2,030,501 1,913,943

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 4,219,577 3,998,317 3,927,207 3,762,809

 HRSG Stack Temperature (o

F) 184 185 186 187

 Molecular weight 28.44 28.39 28.38 28.20

 Volume flow (acfm) 1,164,979 1,107,748 1,089,758 1,052,593

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 51.1 48.6 47.8 46.2

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

SIEMENS H CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 80% LOAD

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

TABLE B-3-SH

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr)

 CT 9 8 8 8

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 9.0 8.0 8.0 8.0

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 12.9 12.0 11.6 10.9

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 11.6 10.8 10.4 9.8

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 3.38 3.15 3.04 2.86

 Total HRSG stack emission rate (lb/hr) [a + b] 12.4 11.2 11.0 10.9

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 2,260,349 2,107,843 2,030,501 1,913,943

 Sulfur content (grains/ 100 cf) 2 2 2 2

 lb SO2 /lb S (64/32) 22 2 2

 HRSG Stack emission rate (lb/hr) 12.9 12.0 11.6 10.9

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppm actual 32.0 31.3 30.4 29.7

 CT / DB, ppmvd @15% O2 25 25 25 25

 Moisture (%) 13.13 13.80 14.67 15.86

 Oxygen (%) 10.60 10.62 10.65 10.57

 Oxygen (%) dry 12.21 12.32 12.48 12.56

 Turbine Flow (acfm) 2,939,582 2,802,860 2,761,508 2,676,221

 Turbine Flow (acfm), dry 2,553,499 2,416,015 2,356,440 2,251,871

 Turbine Exhaust Temperature (°F) 1,165 1,172 1,177 1,185

 CT Emission rate (lb/hr) 218.4 203.1 193.6 182.6

220 205 198 186

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG stack emission rate (lb/hr) (maximum) 17.6 16.4 15.8 14.9

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 m

 Basis, ppm actual 12.8 12.5 12.2 11.9

 Basis, ppmvd @ 15% O2 10 10 10 10

 Moisture (%) 13.13 13.80 14.67 15.86

 Oxygen (%) 10.60 10.62 10.65 10.57

 Oxygen (%) dry 12.21 12.32 12.48 12.56

 Turbine Flow (acfm) 2,939,582 2,802,860 2,761,508 2,676,221

 Turbine Flow (acfm), dry 2,553,499 2,416,015 2,356,440 2,251,871

 Turbine Exhaust Temperature (°F) 1,165 1,172 1,177 1,185

 CT Emission rate (lb/hr) 53.2 49.4 47.1 44.5

54 50 48 45

 HRSG Stack emission rate, ppmvd @ 15% O2 10 10 10 10

 HRSG Stack emission rate (lb/hr) (maximum) 54.0 50.0 48.0 45.0

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppmvd 1.28 1.25 1.22 1.19

 Basis, ppmvd @ 15% O2 11 1 1

 Moisture (%) 13.13 13.80 14.67 15.86

 Oxygen (%) 10.60 10.62 10.65 10.57

 Oxygen (%) dry 12.21 12.32 12.48 12.56

 Turbine Flow (acfm) 2,939,582 2,802,860 2,761,508 2,676,221

 Turbine Flow (acfm), dry 2,553,499 2,416,015 2,356,440 2,251,871

 Turbine Exhaust Temperature (°F) 1,165 1,172 1,177 1,185

 CT Emission rate (lb/hr) 3.04 2.83 2.69 2.54

3.1 2.9 2.8 2.6

 

 HRSG Stack emission rate, ppmvd @ 15% O2 11 1 1

 HRSG Stack emission rate (lb/hr) (maximum) 3.1 2.9 2.8 2.6

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 12.9 12.0 11.6 10.9

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 00 0 0

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after con 11.6 10.8 10.4 9.8

 HRSG Stack emission rate (lb/hr) 2.51 2.34 2.26 2.13

 

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 HRSG Stack emission rate (lb/hr) NA NA NA NA

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

SIEMENS H CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 80% LOAD

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

TABLE B-4 SH

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B4-G80
January 2012 113-87618

 

 

Parameter 35 °F 59 °F 75 °F 95 °F

 

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 1,679 1,589 1,531 1,446

 (MMBtu/hr, HHV) 1,880 1,761 1,697 1,602

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 (Btu/lb, HHV) 23,208 23,208 23,208 23,208

 (HHV/LHV) 1.108 1.108 1.108 1.108

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass flow (lb/hr) 3,570,347 3,422,619 3,374,870 3,259,377

 Temperature (°F) 1,185 1,185 1,185 1,185

 Moisture (% Vol.) 12.72 13.31 14.15 15.29

 Oxygen (% Vol.) 10.87 10.93 10.98 10.93

 Molecular Weight 28.44 28.38 28.38 28.20

 Volume flow (acfm) 2,517,907 2,418,644 2,384,718 2,318,165

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 1,679 1,589 1,531 1,446

 Heat content (Btu/lb, LHV) 20,940 20,940 20,940 20,940

 Fuel usage (lb/hr) 80,181 75,883 73,114 69,054

 Heat content (Btu/cf, LHV) 918 918 918 918

 Fuel density (lb/ft3

) 0.0438 0.0438 0.0438 0.0438

 Fuel usage (cf/hr) 1,828,976 1,730,937 1,667,756 1,575,163

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 3,570,347 3,422,619 3,374,870 3,259,377

 HRSG Stack Temperature (o

F) 184 185 186 187

 Molecular weight 28.44 28.38 28.38 28.20

 Volume flow (acfm) 985,734 948,344 936,491 911,765

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 43.2 41.6 41.1 40.0

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-5-SH

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

SIEMENS CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 60% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B5-G60
January 2012 113-87618

 

Parameter 35 °F 59 °F 75 °F 95 °F

 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr)

 CT 8 8 8 8

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 8.0 8.0 8.0 8.0

 

 b. PM10 [(NH4)2SO4] from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 CT SO2 emission rate (lb/hr) 10.5 9.9 9.5 9.0

 Conversion (%) from SO2 to SO3 in CT 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 9.4 8.9 8.6 8.1

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 2.74 2.59 2.50 2.36

 Total HRSG stack emission rate (lb/hr) [a + b] 10.7 10.6 10.5 10.4

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Natural gas (scf/hr) x sulfur content(gr/100 scf) x 1 lb/7000 gr x (lb SO 2 /lb S) /100

 Fuel use (cf/hr) 1,828,976 1,730,937 1,667,756 1,575,163

 Sulfur content (grains/ 100 cf) 2 2 2 2

 lb SO2 /lb S (64/32) 22 2 2

 HRSG Stack emission rate (lb/hr) 10.5 9.9 9.5 9.0

Nitrogen Oxides

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppm actual 31.2 30.5 29.5 28.7

 CT / DB, ppmvd @15% O2 25 25 25 25

 Moisture (%) 12.72 13.31 14.15 15.29

 Oxygen (%) 10.87 10.93 10.98 10.93

 Oxygen (%) dry 12.45 12.61 12.79 12.90

 Turbine Flow (acfm) 2,517,907 2,418,644 2,384,718 2,318,165

 Turbine Flow (acfm), dry 2,197,540 2,096,640 2,047,318 1,963,653

 Turbine Exhaust Temperature (°F) 1,185 1,185 1,185 1,185

 CT Emission rate (lb/hr) 180.4 169.0 161.3 152.7

180 168 162 153

 HRSG Stack emission rate, ppmvd @ 15% O2 2.0 2.0 2.0 2.0

 HRSG stack emission rate (lb/hr) (maximum) 14.4 13.5 13.0 12.2

Carbon Monoxide

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 m

 Basis, ppm actual 12.5 12.2 11.8 11.5

 Basis, ppmvd @ 15% O2 10 10 10 10

 Moisture (%) 12.72 13.31 14.15 15.29

 Oxygen (%) 10.87 10.93 10.98 10.93

 Oxygen (%) dry 12.45 12.61 12.79 12.90

 Turbine Flow (acfm) 2,517,907 2,418,644 2,384,718 2,318,165

 Turbine Flow (acfm), dry 2,197,540 2,096,640 2,047,318 1,963,653

 Turbine Exhaust Temperature (°F) 1,185 1,185 1,185 1,185

 CT Emission rate (lb/hr) 43.9 41.1 39.3 37.2

44 41 40 37

 HRSG Stack emission rate, ppmvd @ 15% O2 10 10 10 10

 HRSG Stack emission rate (lb/hr) (maximum) 44.0 41.1 40.0 37.2

Volatile Organic Compounds

 Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x

 Basis, ppmvd 1.25 1.22 1.18 1.15

 Basis, ppmvd @ 15% O2 11 1 1

 Moisture (%) 12.72 13.31 14.15 15.29

 Oxygen (%) 10.87 10.93 10.98 10.93

 Oxygen (%) dry 12.45 12.61 12.79 12.90

 Turbine Flow (acfm) 2,517,907 2,418,644 2,384,718 2,318,165

 Turbine Flow (acfm), dry 2,197,540 2,096,640 2,047,318 1,963,653

 Turbine Exhaust Temperature (°F) 1,185 1,185 1,185 1,185

 CT Emission rate (lb/hr) 2.51 2.35 2.24 2.12

2.5 2.4 2.3 2.1

 HRSG Stack emission rate, ppmvd @ 15% O2 11 1 1

 HRSG Stack emission rate (lb/hr) (maximum) 2.5 2.4 2.3 2.1

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO2 emission (lb/hr) x Conversion to H2SO4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 10.5 9.9 9.5 9.0

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 00 0 0

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after con 9.4 8.9 8.6 8.1

 SCR Conversion to H2SO4 (% by weight) 33 3 3

 HRSG Stack emission rate (lb/hr) 2.03 1.92 1.85 1.75

 

Lead 

 Lead (lb/hr) = NA

 Emission Rate Basis NA NA NA NA

 HRSG Stack emission rate (lb/hr) NA NA NA NA

 

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-6-SH

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

SIEMENS H CT, DRY LOW NOx COMBUSTOR, NATURAL GAS, 60% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B6-G60
January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,522 2,406 2,300 2,201

 (MMBtu/hr, HHV) 2,690 2,567 2,453 2,347

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,613 19,613 19,613 19,613

 (HHV/LHV) 1.067 1.067 1.067 1.067

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 5,193,512 4,963,007 4,767,933 4,458,381

 Temperature (°F) 1,080 1,093 1,102 1,117

 Moisture (% Vol.) 12.84 14.03 15.12 16.86

 Oxygen (% Vol.) 10.56 10.42 10.31 10.09

 Molecular Weight 28.64 28.60 28.52 28.41

 Volume flow (acfm) 3,404,546 3,285,816 3,184,183 3,017,384

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,522 2,406 2,300 2,201

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 137,162 130,853 125,088 119,704

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 5,193,512 4,963,007 4,767,933 4,458,381

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.64 28.60 28.52 28.41

 Volume flow (acfm) 1,810,600 1,728,597 1,661,402 1,557,483

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 79.4 75.8 72.8 68.3

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

Turbine Inlet Temperature

SIEMENS CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

TABLE B-7-SH

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B7-O100
January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 CT 59 56 54 51

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 59.0 56.0 54.0 51.0

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 4.1 3.9 3.8 3.6

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 3.7 3.5 3.4 3.2

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 1.08 1.03 0.98 0.94

 Total HRSG stack emission rate (lb/hr) [a + b] 60.1 57.0 55.0 51.9

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 137,162 130,853 125,088 119,704

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 4.1 3.9 3.8 3.6

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NOx (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 54.5 53.7 52.9 51.9

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 12.84 14.03 15.12 16.86

 Oxygen (%) 10.56 10.42 10.31 10.09

 Oxygen (%) dry 12.12 12.12 12.15 12.13

 Turbine Flow (acfm) 3,404,546 3,285,816 3,184,183 3,017,384

 Turbine Flow (acfm), dry 2,967,475 2,824,706 2,702,796 2,508,730

 Turbine Exhaust Temperature (°F) 1,080 1,093 1,102 1,117

 CT Emission rate (lb/hr) 454.6 428.8 406.7 374.7

466 444 425 406.0

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) (maximum) 88.8 84.6 81.0 77.3

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 13.0 12.8 12.6 12.4

 Basis, ppmvd @ 15% O2 10 10 10 10

 Moisture (%) 12.84 14.03 15.12 16.86

 Oxygen (%) 10.56 10.42 10.31 10.09

 Oxygen (%) dry 12.12 12.12 12.15 12.13

 Turbine Flow (acfm) 3,404,546 3,285,816 3,184,183 3,017,384

 Turbine Flow (acfm), dry 2,967,475 2,824,706 2,702,796 2,508,730

 Turbine Exhaust Temperature (°F) 1,080 1,093 1,102 1,117

 CT Emission rate (lb/hr) 65.9 62.1 58.9 54.3

68 64 62 59

 HRSG Stack emission rate, ppmvd @ 15% O2 10 10 10 10

 HRSG Stack emission rate (lb/hr) (maximum) 68.0 64.0 62.0 59.0

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH 4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 1.3 1.3 1.3 1.2

 Basis, ppmvd @ 15% O2 1.0 1.0 1.0 1.0

 Moisture (%) 12.84 14.03 15.12 16.86

 Oxygen (%) 10.56 10.42 10.31 10.09

 Oxygen (%-dry) 12.12 12.12 12.15 12.13

 Turbine Flow (acfm) 3,404,546 3,285,816 3,184,183 3,017,384

 Turbine Flow (acfm), dry 2,967,475 2,824,706 2,702,796 2,508,730

 Turbine Exhaust Temperature (°F) 1,080 1,093 1,102 1,117

 CT Emission rate (lb/hr) 3.8 3.6 3.4 3.1

3.9 3.7 3.5 3.4

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) (maximum) 39.0 37.0 35.0 34.0

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 4.1 3.9 3.8 3.6

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversion 3.7 3.5 3.4 3.2

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.80 0.76 0.73 0.70

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr)- calculated 0.0377 0.0359 0.0343 0.0329

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

TABLE B-8-SH

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January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 2,101 1,976 1,883 1,774

 (MMBtu/hr, HHV) 2,242 2,108 2,008 1,893

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,613 19,613 19,613 19,613

 (HHV/LHV) 1.060 1.060 1.060 1.060

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 4,195,327 4,031,921 3,902,311 3,738,668

 Temperature (°F) 1,141 1,148 1,152 1,160

 Moisture (% Vol.) 12.95 13.54 14.42 15.64

 Oxygen (% Vol.) 10.32 10.39 10.38 10.33

 Molecular Weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 2,857,705 2,764,193 2,688,976 2,599,283

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 2,101 1,976 1,883 1,774

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 114,266 107,467 102,409 96,481

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 4,195,327 4,031,921 3,902,311 3,738,668

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 1,461,874 1,404,444 1,359,501 1,306,060

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 64.1 61.6 59.6 57.3

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-9-SH

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 80% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B9-O80
January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 CT 48 46 44 42

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 48.0 46.0 44.0 42.0

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 3.4 3.2 3.1 2.9

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 3.1 2.9 2.8 2.6

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 0.90 0.84 0.80 0.76

 Total HRSG stack emission rate (lb/hr) [a + b] 48.9 46.8 44.8 42.8

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 114,266 107,467 102,409 96,481

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 3.4 3.2 3.1 2.9

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 56.1 54.6 53.4 51.9

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 12.95 13.54 14.42 15.64

 Oxygen (%) 10.32 10.39 10.38 10.33

 Oxygen (%) dry 11.85 12.02 12.13 12.25

 Turbine Flow (acfm) 2,857,705 2,764,193 2,688,976 2,599,283

 Turbine Flow (acfm), dry 2,487,654 2,389,887 2,301,185 2,192,672

 Turbine Exhaust Temperature (°F) 1,141 1,148 1,152 1,160

 CT Emission rate (lb/hr) 377.5 354.4 336.1 314.4

388 365 348 327

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) (maximum) 73.9 69.5 66.3 62.3

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 13.3 13.0 12.7 12.4

 Basis, ppmvd @ 15% O2 10 10 10 10

 Moisture (%) 12.95 13.54 14.42 15.64

 Oxygen (%) 10.32 10.39 10.38 10.33

 Oxygen (%) dry 11.85 12.02 12.13 12.25

 Turbine Flow (acfm) 2,857,705 2,764,193 2,688,976 2,599,283

 Turbine Flow (acfm), dry 2,487,654 2,389,887 2,301,185 2,192,672

 Turbine Exhaust Temperature (°F) 1,141 1,148 1,152 1,160

 CT Emission rate (lb/hr) 54.7 51.4 48.7 45.6

56.0 53 50 47

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) (maximum) 56.0 53.0 50.0 47.0

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 1.3 1.3 1.3 1.2

 Basis, ppmvd @ 15% O2 1.0 1.0 1.0 1.0

 Moisture (%) 12.95 13.54 14.42 15.64

 Oxygen (%) 10.32 10.39 10.38 10.33

 Oxygen (%-dry) 11.85 12.02 12.13 12.25

 Turbine Flow (acfm) 2,857,705 2,764,193 2,688,976 2,599,283

 Turbine Flow (acfm), dry 2,487,654 2,389,887 2,301,185 2,192,672

 Turbine Exhaust Temperature (°F) 1,141 1,148 1,152 1,160

 CT Emission rate (lb/hr) 3.1 2.9 2.8 2.6

3.2 3.0 2.9 2.7

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) (maximum) 32.0 30.0 29.0 27.0

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 3.4 3.2 3.1 2.9

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversion) 3.1 2.9 2.8 2.6

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.67 0.63 0.60 0.56

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr) 0.0314 0.0295 0.0281 0.0265

 

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-10-SH

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 80% LOAD

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B10-080
January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Combustion Turbine Performance

 Heat Input (MMBtu/hr, LHV) 1,920 1,808 1,724 1,626

 (MMBtu/hr, HHV) 2,048 1,928 1,839 1,734

 Relative Humidity (%) 60 60 60 50

 Fuel heating value (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 (Btu/lb, HHV) 19,613 19,613 19,613 19,613

 (HHV/LHV) 1.060 1.060 1.060 1.060

CT/DB Exhaust Flow

Volume flow (acfm) = [Mass flow (lb/hr) x 1545.4 x Temp (oF + 460 K)] / [2112.5 x 60 min/hr x MW]

 Mass Flow (lb/hr) 3,792,624 3,669,929 3,569,152 3,443,853

 Temperature (°F) 1,182 1,182 1,182 1,182

 Moisture (% Vol.) 12.95 13.48 14.31 15.47

 Oxygen (% Vol.) 10.26 10.37 10.38 10.39

 Molecular Weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 2,649,291 2,568,962 2,505,426 2,426,588

 

Fuel Usage

 Fuel usage (lb/hr) = Heat Input (MMBtu/hr) x 1,000,000 Btu/MMBtu [Fuel Heat Content, Btu/lb (LHV)]

 Heat input (MMBtu/hr, LHV) 1,920 1,808 1,724 1,626

 Heat content (Btu/lb, LHV) 18,387 18,387 18,387 18,387

 Fuel usage (lb/hr) 104,422 98,330 93,762 88,432

HRSG Stack 

 HRSG - Stack Height (feet) 149 149 149 149

 Diameter (feet) 22 22 22 22

HRSG Stack Flow Conditions

 Velocity (ft/sec) = Volume flow (acfm) / [((diameter)2 /4) x 3.14159] / 60 sec/min

 Mass flow (lb/hr) 3,792,624 3,669,929 3,569,152 3,443,853

 HRSG Stack Temperature (o

F) 359 357 355 354

 Molecular weight 28.66 28.60 28.52 28.41

 Volume flow (acfm) 1,321,419 1,278,223 1,243,558 1,202,949

 Diameter (feet) 22 22 22 22

 Velocity (ft/sec) 57.9 56.0 54.5 52.7

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-11-SH

DESIGN INFORMATION AND STACK PARAMETERS

FOR THE PEEC PROJECT

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 70% LOAD

Turbine Inlet Temperature

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B11-O70
January 2012 113-87618

Turbine Inlet Temperature

Parameter 35 °F 59 °F 75 °F 95 °F 

Particulate (including PM2.5) from CT and SCR

 Total PM10 = PM10 (front half) + PM10 [(NH4)2SO4] in HRSG only (back-half)

 a. PM10 (front half) (lb/hr) 

 CT 43 42 40 39

 DB (lb/hr) 0.0 0.0 0.0 0.0

 Total CT/DB emission rate (lb/hr) 43.0 42.0 40.0 39.0

 b. PM10 ((NH4)2SO4) from HRSG only (back half) = Sulfur trioxide from conversion of SO2 converts to ammonium sulfate (= PM10)

 Particulate from conversion of SO 2 = SO 2 emissions (lb/hr) x conversion of SO 2 to SO 3 in CT and in SCR x lb SO 3 /lb SO 2 x

 conversion of SO 3 to (NH 4 ) 2 SO 4 x lb (NH 4 ) 2 SO 4 / lb SO 3

 SO2 emission rate (lb/hr) 3.1 2.9 2.8 2.7

 Conversion (%) from SO2 to SO3 10.0 10.0 10.0 10.0

 Remaining SO2 (lb/hr) in CT after conversion 2.8 2.7 2.5 2.4

 Conversion (%) from SO2 to SO3 in SCR 3.0 3.0 3.0 3.0

 MW SO3/ SO2 (80/64) 1.3 1.3 1.3 1.3

 Conversion (%) from SO3 to (NH4)2(SO4) 100 100 100 100

 MW (NH4)2 SO4/ SO3 (132/80) 1.7 1.7 1.7 1.7

 HRSG Particulate as (NH4)2(SO4) (lb/hr) 0.82 0.77 0.74 0.69

 Total HRSG stack emission rate (lb/hr) [a + b] 43.8 42.8 40.7 39.7

 (lb/mmBtu, HHV) NA NA NA NA

Sulfur Dioxide 

 SO 2 (lb/hr)= Fuel oil (lb/hr) x sulfur content(% weight) x (lb SO 2 /lb S) /100

 Fuel oil Sulfur Content 0.0015% 0.0015% 0.0015% 0.0015%

 Fuel oil use (lb/hr) 104,422 98,330 93,762 88,432

 lb SO2 / lb S (64/32) 2222

 HRSG Stack emission rate (lb/hr) 3.1 2.9 2.8 2.7

Nitrogen Oxides

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 NO x (ppm actual) = NO x (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 NO x (lb/hr) = NO x (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NOx ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 56.5 54.9 53.6 51.8

 CT/DB, ppmvd @15% O2 42 42 42 42

 Moisture (%) 12.95 13.48 14.31 15.47

 Oxygen (%) 10.26 10.37 10.38 10.39

 Oxygen (%) dry 11.78 11.98 12.12 12.29

 Turbine Flow (acfm) 2,649,291 2,568,962 2,505,426 2,426,588

 Turbine Flow (acfm), dry 2,306,229 2,222,724 2,146,882 2,051,201

 Turbine Exhaust Temperature (°F) 1,182 1,182 1,182 1,182

 CT Emission rate (lb/hr) - calculated 344.0 324.2 308.4 288.9

355 334 318 300

 HRSG Stack emission rate, ppmvd @ 15% O2 8.0 8.0 8.0 8.0

 HRSG Stack emission rate (lb/hr) (maximum) 67.6 63.6 60.6 57.1

Carbon Monoxide

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 CO (ppmv wet or actual) = CO (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 CO (lb/hr) = CO (ppm actual) x Volume flow (acfm) x 28 (mole. wgt CO) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 13.5 13.1 12.8 12.3

 Basis, ppmvd @ 15% O2 10 10 10 10

 Moisture (%) 12.95 13.48 14.31 15.47

 Oxygen (%) 10.26 10.37 10.38 10.39

 Oxygen (%) dry 11.78 11.98 12.12 12.29

 Turbine Flow (acfm) 2,649,291 2,568,962 2,505,426 2,426,588

 Turbine Flow (acfm), dry 2,306,229 2,222,724 2,146,882 2,051,201

 Turbine Exhaust Temperature (°F) 1,182 1,182 1,182 1,182

 CT Emission rate (lb/hr) 49.9 47.0 44.7 41.9

51 48 46 43

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) (maximum) 51.0 48.0 46.0 43.0

Volatile Organic Compounds

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 VOC (ppmv wet or actual) = VOC (ppmvd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 VOC (lb/hr) = VOC (ppm actual) x Volume flow (acfm) x 16 (mole. wgt CH4 ) x 2112.5 lb/ft 2 (pressure) / [1545.4 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 Basis, ppm actual 1.3 1.3 1.3 1.2

 Basis, ppmvd @ 15% O2 1.0 1.0 1.0 1.0

 Moisture (%) 12.95 13.48 14.31 15.47

 Oxygen (%) 10.26 10.37 10.38 10.39

 Oxygen (%-dry) 11.78 11.98 12.12 12.29

 Turbine Flow (acfm) 2,649,291 2,568,962 2,505,426 2,426,588

 Turbine Flow (acfm), dry 2,306,229 2,222,724 2,146,882 2,051,201

 Turbine Exhaust Temperature (°F) 1,182 1,182 1,182 1,182

 CT Emission rate (lb/hr) 2.8 2.7 2.6 2.4

2.9 2.8 2.6 2.5

 HRSG Stack emission rate, ppmvd @ 15% O2 10.0 10.0 10.0 10.0

 HRSG Stack emission rate (lb/hr) (maximum) 29.0 28.0 26.0 25.0

Sulfuric Acid Mist

 Sulfuric Acid Mist (lb/hr)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100

 CT SO2 emission rate (lb/hr) 3.1 2.9 2.8 2.7

 CT Conversion to H2SO4 (% by weight) 10 10 10 10

 DB SO2 emission rate (lb/hr) 0000

 DB Conversion to H2SO4 (%) 20 20 20 20

 SCR SO2 emission rate (lb/hr) - calculated (remaining SO2 after conversion) 2.8 2.7 2.5 2.4

 SCR Conversion to H2SO4 (% by weight) 3333

 HRSG Stack emission rate (lb/hr) 0.61 0.57 0.55 0.52

 

Lead 

 Lead (lb/hr) = Basis (lb/10 12 Btu) x Heat Input (MMBtu/hr) / 1,000,000 MMBtu/10 12 Btu

 Emission Rate Basis (lb/1012 Btu) 14 14 14 14

 HRSG Stack emission rate (lb/hr)- calculated 0.0287 0.0270 0.0257 0.0243

 

Note: Universal gas constant = 1,545.4 ft-lb(force)/°R; atmospheric pressure = 2,112.5 lb(force)/ft2 (@14.67 psia).

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-12 SH

MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, 70% LOAD

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Parameter 35 °F 59 °F 75 °F 95 °F

 

Formaldehyde (CH2O)

 CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 30 (mole. wgt CH2 O) x 2116.8 lb/ft 2 (pressure) / 

 [1545.7 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 CH 2 O (ppm actual) = CH 2 O (ppmd @ 15%O2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x (1- Moisture(%)/100)

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 Basis, ppm actual- calculated 0.116 0.115 0.139 0.111

 CT, ppmvd @15% O2 0.091 0.091 0.091 0.091

 Moisture (%) 13.08 14.25 15.12 17.11

 Oxygen (%) 10.63 10.48 8.72 10.11

 Oxygen (%) dry 12.23 12.22 10.27 12.20

 Exhaust Flow (acfm) 1,439,293 1,377,881 1,406,457 1,275,068

 Exhaust Temperature (°F) 196 195 185 195

 Molecular weight 30 30 30 30

 CT Emission rate (lb/hr) 0.627 0.594 0.747 0.533

 CT Emission rate (lb/1012 Btu) (HHV) 226.2 224.3 282.0 219.1 

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-13a-SH

CT Only at Baseload

Turbine Inlet Temperature

WHEN FIRING NATURAL GAS, SIEMENS H CT

MAXIMUM FORMALDEHYDE EMISSIONS

FOR THE PEEC PROJECT

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Emission Rate (lb/hr) 

Parameter firing Natural Gas Maximum Annual

 - Base Load a Emission (TPY) b

Ambient Temperature (oF): 75 °F 1 3

HIR (MMBtu/hr): 2,539 CT/HRSG CTs/HRSGs

Sulfuric acid mist 2.10 9.2 27.6

HAPs [Section 112(b) of Clean Air Act]

1,3-Butadiene 0.0011 0.0048 0.014

Acetaldehyde 0.10 0.44 1.33

Acrolein 0.016 0.07 0.21

Benzene 0.030 0.13 0.40

Ethylbenzene 0.081 0.36 1.07

Formaldehyde 0.59 2.60 7.80

Naphthalene 0.0033 0.01 0.04

Polycyclic Aromatic Hydrocarbons (PAH) c 0.0056 0.02 0.07

Propylene Oxide 0.074 0.32 0.97

Toluene 0.084 0.37 1.10

Xylene 0.16 0.71 2.14

Antimony 0.0 0.00 0.00

Arsenic 0.0 0.00 0.00

Beryllium 0.0 0.00 0.00

Cadmium 0.0 0.00 0.00

Chromium 0.0 0.00 0.00

Lead 0.0 0.00 0.00

Manganese 0.0 0.00 0.00

Mercury 0.0000025 0.00 0.00

Nickel 0.0 0.00 0.00

Selenium 0.0 0.00 0.00

HAPs (Total) 1.15 5.05 15.2

a

 Emissions based on the following emission factors and conversion factors for firing natural gas:

Emission Factors Value Reference

Sulfuric acid mist 10 %; Conversion of SO2 to SO3 in gas turbine

1,3-Butadiene (a) 0.43 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Acetaldehyde 40 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Acrolein 6.4 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Benzene 12 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Ethylbenzene 32 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Formaldehyde 0.091 ppmvd @15% O2 (see Table 9a) 

Naphthalene 1.3 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Polycyclic Aromatic Hydrocarbons (PAH) 2.2 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Propylene Oxide (a) 29 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Toluene 33 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000. Database

Xylene 64 lb/1012 Btu; AP-42,Table 3.1-3. EPA 2000

Antimony 0.00E+00

Arsenic 0.00E+00

Beryllium 0.00E+00

Cadmium 0.00E+00

Chromium 0.00E+00

Lead 0.00E+00

Manganese 0.00E+00

Mercury 1.00E-03

Nickel 0.00E+00

Selenium 0.00E+00

 (a) Based on 1/2 the detection limit; expected emissions are lower.

b Annual emissions based on firing natural gas for : 8760 hours. . 

c

 Assumed to be representative of Polycyclic Organic Matter (POM) emissions, a regulated HAP.

TABLE B-13-SH

WHEN FIRING NATURAL GAS, SIEMENS H CT

REGULATED AND HAZARDOUS AIR POLLUTANT EMISSION FACTORS AND EMISSIONS

FOR THE PEEC PROJECT

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Parameter 35 °F 59 °F 75 °F 95 °F 

Formaldehyde (CH2O) 

 CH 2 O (lb/hr) = CH2 O (ppm actual) x Volume flow (acfm) x 30 (mole. wgt CH2 O) x 2116.8 lb/ft 2 (pressure) / 

 [1545.7 (gas constant, R) x Actual Temp. (°R)] x 60 min/hr

 CH 2 O (ppm actual) = CH 2 O (ppmd @ 15%O 2 ) x [(20.9 - O2 dry)/(20.9 - 15)] x [1- Moisture(%)/100]

 Oxygen (%, dry)(O2 dry) = Oxygen (%)/[1-Moisure (%)]

 Basis, ppmvw - calculated 0.118 0.116 0.115 0.112

 CT, ppmvd @15% O2 0.091 0.091 0.091 0.091

 Moisture (%) 12.84 14.03 15.11805657 16.85745512

 Oxygen (%) 10.56 10.42 10.31 10.09

 Oxygen (%) dry 12.12 12.12 12.15 12.13

 Exhaust Flow (acfm) 1,810,600 1,728,597 1,661,402 1,557,483

 Exhaust Temperature (°F) 359 357 355 354

 Molecular weight 30 30 30 30

 CT Emission rate (lb/hr) 0.642 0.606 0.575 0.529

 CT Emission rate (lb/1012 Btu) (HHV) 238.8 236.0 234.3 225.6 

Note: ppmvd= parts per million, volume dry; O2= oxygen.

Source: Siemens, 2011; CT Performance Data; Golder, 2011.

TABLE B-14a-SH

CT Only

Turbine Inlet Temperature

SIEMENS H CT, DRY LOW NOx COMBUSTOR, DISTILLATE OIL, BASE LOAD

MAXIMUM FORMALDEHYDE EMISSIONS

FOR THE PEEC PROJECT

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Emission Rate (lb/hr) Emission Rate (lb/hr)

Parameter Distillate Fuel Oil a Natural Gas b

1 CT/HRSG - Base Load 1 CT/HRSG - Base Load

Ambient Temperature (o

F): 75 °F 75 °F

HIR (MMBtu/hr): 2,453 2,539 500 1,000 1,500 500 1,000 1,500

Sulfuric acid mist 0.73 2.10 0.55 1.09 1.64 26.6 25.5 24.5

HAPs [Section 112(b) of Clean Air Act]

1,3-Butadiene 0.0392 0.001 0.029 0.059 0.088 0.043 0.072 0.100

Acetaldehyde 0.00 0.102 0.000 0.000 0.000 1.26 1.18 1.11

Acrolein 0.00 0.016 0.00 0.00 0.00 0.20 0.19 0.18

Benzene 0.135 0.030 0.10 0.20 0.30 0.48 0.56 0.64

Ethylbenzene 0.00 0.081 0.00 0.00 0.00 1.01 0.95 0.88

Formaldehyde 0.606 0.594 0.45 0.91 1.36 7.81 7.82 7.83

Naphthalene 0.0859 0.003 0.064 0.129 0.193 0.11 0.17 0.23

Polycyclic Aromatic Hydrocarbons (PAH) c 0.098 0.006 0.074 0.147 0.221 0.14 0.21 0.28

Propylene Oxide 0.00 0.074 0.00 0.00 0.00 0.91 0.86 0.80

Toluene 0.00 0.084 0.00 0.00 0.00 1.04 0.98 0.91

Xylene 0.00 0.162 0.00 0.00 0.00 2.01 1.89 1.77

Antimony 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Arsenic 0.0270 0.00 0.020 0.040 0.061 0.02 0.04 0.06

Beryllium 0.000760 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cadmium 0.01177 0.00 0.01 0.02 0.03 0.01 0.02 0.03

Chromium 0.0270 0.00 0.02 0.04 0.06 0.02 0.04 0.06

Lead 0.0343 0.00 0.026 0.052 0.077 0.03 0.05 0.08

Manganese 1.94 0.00 1.45 2.91 4.36 1.45 2.91 4.36

Mercury 0.00294 0.00 0.002 0.004 0.007 0.00 0.00 0.01

Nickel 0.01128 0.00 0.008 0.017 0.025 0.01 0.02 0.03

Selenium 0.0613 0.00 0.05 0.09 0.14 0.05 0.09 0.14

HAPs (Total) 3.08 1.2 2.31 4.62 6.93 16.6 18.0 19.5

a

 Emissions based on the following emission factors and conversion factors for firing distillate fuel oil:

Emission Factors Value Reference

Sulfuric acid mist 5 %; Conversion of SO2 to SO3 in gas turbine

1,3-Butadiene (a) 16 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Acetaldehyde 0.0 

Acrolein 0.0 

Benzene 55 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Ethylbenzene 0.0

Formaldehyde 0.091 ppmvd @15% O2 (see Table 10a) 

Naphthalene 35 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Polycyclic Aromatic Hydrocarbons (PAH) 40 lb/1012 Btu; AP-42,Table 3.1-4. EPA 2000

Propylene Oxide 0.0 

Toluene 0.0 

Xylene 0.0

 

Antimony 0.0 

Arsenic (a) 11 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Beryllium (a) 0.31 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Cadmium 4.8 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Chromium 11 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Lead 14 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Manganese 790 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Mercury 1.2 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Nickel (a) 4.6 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

Selenium (a) 25 lb/1012 Btu; AP-42,Table 3.1-5. EPA 2000

 (a) Based on 1/2 the detection limit; expected emissions are lower.

b

 Natural gas firing emission rates based on Table B-13.

c

 Assumed to be representative of Polycyclic Organic Matter (POM) emissions, a regulated HAP

TABLE B-14-SH

Maximum Annual Emissions (TPY)

Maximum Annual Emissions (TPY)

REGULATED AND HAZARDOUS AIR POLLUTANT EMISSION FACTORS AND EMISSIONS FOR THE PEEC PROJECT

Natural Gas and Fuel Oil

WHEN FIRING DISTILLATE FUEL OIL, SIEMENS H CT

3 CTs/HRSGs

- Hours on Distillate Fuel Oil Only

3 CTs/HRSGs

- Hours on Distillate Fuel Oil

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Parameter Units Value Fire Pump Engine Emergency Generators 

Number 1 2

Heat Input Rate MMBtu/hr per unit 2.32 21.0

Maximum operation/yr hours per unit 100 100

Heat Input Rate/annual MMBtu/yr all units 232.4 4,202.0

HAPs [Section 112(b) of Clean Air Act]

Acrolein lb/MMBtu 7.88E-06 9.16E-07 1.66E-05 

Acetaldehyde lb/MMBtu 2.52E-05 2.93E-06 5.29E-05

Benzene lb/MMBtu 7.76E-04 9.02E-05 1.63E-03

Formaldehyde lb/MMBtu 7.89E-05 9.17E-06 1.66E-04

Naphthalene lb/MMBtu 1.30E-04 1.51E-05 2.73E-04

Toluene lb/MMBtu 2.81E-04 3.26E-05 5.90E-04

Xylene lb/MMBtu 1.93E-04 2.24E-05 4.05E-04

Acenaphthene lb/MMBtu 4.68E-06 5.44E-07 9.83E-06

Acenaphthylene lb/MMBtu 9.23E-06 1.07E-06 1.94E-05

Anthracene lb/MMBtu 1.23E-06 1.43E-07 2.58E-06

Benzo(a)anthracene lb/MMBtu 6.22E-07 7.23E-08 1.31E-06

Benzo(b)fluoranthene lb/MMBtu 1.11E-06 1.29E-07 2.33E-06

Benzo(k)fluoranthene lb/MMBtu 2.18E-07 2.53E-08 4.58E-07

Benzo(g,h,i)perylene lb/MMBtu 5.56E-07 6.46E-08 1.17E-06

Benzo(a)pyrene lb/MMBtu 2.57E-07 2.99E-08 5.40E-07

Chrysene lb/MMBtu 1.53E-06 1.78E-07 3.21E-06

Dibenzo(a,h)anthracene lb/MMBtu 3.46E-07 4.02E-08 7.27E-07

Fluoanthene lb/MMBtu 4.03E-06 4.68E-07 8.47E-06

Fluorene lb/MMBtu 4.47E-06 5.19E-07 9.39E-06

Indo(1,2,3-cd)pyrene lb/MMBtu 4.14E-07 4.81E-08 8.70E-07

Phenanthrene lb/MMBtu 1.05E-06 1.22E-07 2.21E-06

Pyrene lb/MMBtu 3.71E-06 4.31E-07 7.79E-06

 

Arsenic lb/1012 Btu 4.0 4.65E-07 8.40E-06

Beryllium lb/1012 Btu 3.0 3.49E-07 6.30E-06

Cadmium lb/1012 Btu 3.0 3.49E-07 6.30E-06

Chromium lb/1012 Btu 3.0 3.49E-07 6.30E-06

Lead lb/1012 Btu 9.0 1.05E-06 1.89E-05

Mercury lb/1012 Btu 3.0 3.49E-07 6.30E-06

Manganese lb/1012 Btu 6.0 6.97E-07 1.26E-05

Nickel lb/1012 Btu 3.0 3.49E-07 6.30E-06

Selenium lb/1012 Btu 15.0 1.74E-06 3.15E-05

HAPs (Total) 1.83E-04 3.31E-03

a

 EPA AP-42, Section 3.4, Large Stationary Diesel And All Stationary Dual-fuel Engines (October 1996)

b

 EPA AP-42, Section 1.3, Fuel Oil Combustion for metals (September 1998).

TABLE B-15

HAZARDOUS AIR POLLUTANT EMISSIONS

Emission Factor a, b 

Annual Emission Basis

Emissions (TPY)

FOR ADDITIONAL PEEC EMISSION UNITS- OIL-FIRING

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Parameter/Pollutant Units Value

Annual Emission 

Basis Units Value

Annual Emission 

Basis

Number 1 2

Heat Input Rate MMBtu/hr per unit 9.90 MMBtu/hr per unit 53.98

Fuel use scf/hr per unit 9,706 scf/hr per unit NA

Maximum operation/yr hours per unit 8,760 hours per unit 8,760

Heat Input Rate/annual MMBtu/yr all units NA MMBtu/yr all units 945,760

Fuel use/annual MMscf/yr all units 85.02 MMscf/yr all units NA

HAPs [Section 112(b) of Clean Air Act] Emissions (TPY) Emissions (TPY)

Benzene lb/106 scf 2.10E-03 8.93E-05 lb/1012 Btu 1.20E+01 5.67E-03

Formaldehyde lb/106 scf 7.50E-02 3.19E-03 lb/1012 Btu 7.10E+02 3.36E-01

Naphthalene lb/106 scf 6.10E-04 2.59E-05 lb/1012 Btu 1.30E+00 6.15E-04

Toluene lb/106 scf 3.40E-03 1.45E-04 lb/1012 Btu 3.30E+01 1.56E-02

Dichlorobenzene lb/106 scf 1.20E-03 5.10E-05 -- NA NA

Acenaphthene lb/106 scf 1.80E-06 7.65E-08 -- NA NA

Acenaphthylene lb/106 scf 1.80E-06 7.65E-08 -- NA NA

Acetaldehyde -- NA NA lb/1012 Btu 4.00E+01 1.89E-02

Acrolein -- NA NA lb/1012 Btu 6.40E+00 3.03E-03

Anthracene lb/106 scf 2.40E-06 1.02E-07 -- NA NA

Benzo(a)anthracene lb/106 scf 1.80E-06 7.65E-08 -- NA NA

Benzene lb/106 scf 2.10E-03 8.93E-05 lb/1012 Btu 1.20E+01 5.67E-03

Benzo(g,h,i)perylene lb/106 scf 1.20E-06 5.10E-08 -- NA NA

Chrysene lb/106 scf 1.80E-06 7.65E-08 -- NA NA

Dibenzo(a,h)anthracene lb/106 scf 1.20E-06 5.10E-08 -- NA NA

Ethylbenzene -- NA NA lb/1012 Btu 3.20E+01 1.51E-02

Fluoanthene lb/106 scf 3.00E-06 1.28E-07 -- NA NA

Fluorene lb/106 scf 2.80E-06 1.19E-07 -- NA NA

Indeno(1,2,3-cd)pyrene lb/106 scf 1.80E-06 7.65E-08 -- NA NA

Phenanthrene lb/106 scf 1.70E-05 7.23E-07 -- NA NA

Phenol -- NA NA -- NA NA

Pyrene lb/106 scf 5.00E-06 2.13E-07 -- NA NA

Xylene -- NA NA lb/1012 Btu 6.40E+01 3.03E-02

1,3-Butadiene -- NA NA lb/1012 Btu 4.30E-01 2.03E-04

Polycyclic Aromatic Hydrocarbons (PAH) -- NA NA lb/1012 Btu 2.20E+00 1.04E-03

Propylene Oxide -- NA NA lb/1012 Btu 2.90E+01 1.37E-02

Arsenic lb/106 scf 2.00E-04 8.50E-06 -- NA NA

Beryllium lb/106 scf 1.20E-05 5.10E-07 -- NA NA

Cadmium lb/106 scf 1.10E-03 4.68E-05 -- NA NA

Chromium lb/106 scf 1.40E-03 5.95E-05 -- NA NA

Cobalt lb/106 scf 8.40E-05 3.57E-06 -- NA NA

Mercury lb/106 scf 2.60E-04 1.11E-05 -- NA NA

Manganese lb/106 scf 3.80E-04 1.62E-05 -- NA NA

Nickel lb/106 scf 2.10E-03 8.93E-05 -- NA NA

Selenium lb/106 scf 2.40E-05 1.02E-06 -- NA NA

HAPs (Total) 3.83E-03 0.45

a

 EPA AP-42, Section 1.4, Natural Gas Combustion (March 1998).

b

 EPA AP-42, Section 3.2, Stationary Gas Turbines (April 2000).

TABLE B-16

HAZARDOUS AIR POLLUTANT EMISSIONS

Fuel Heater Compressor Station

Emission Factor a Emission Factor b 

FOR ADDITIONAL PEEC EMISSION UNITS- NATURAL GAS-FIRING

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Pollutant Natural Gas

Distillate Fuel 

Oil Natural Gas

Distillate 

Fuel Oil Natural Gas

Distillate 

Fuel Oil

Natural 

Gas

Distillate 

Fuel Oil Natural Gas

Distillate 

Fuel Oil Natura

Natural Gas Only

CO2 2,539.0 0.0 116.9 163.0 296,697.6 0.0 8760 0 1,299,535.4 0 1,299,5

CH4 2,539.0 0.0 0.002204 0.006612 5.6 0.0 8760 0 24.5 0 514

N2O 2,539.0 0.0 0.0002204 0.001322 0.6 0.0 8760 0 2.5 0 759

Total 1,300,8

Natural Gas & Distillate Fuel Oil

CO2 2,539.0 2,453.0 116.9 163.0 296,697.6 399,858.2 7760 1000 1,151,186.6 199,929.1 1,151,1

CH4 2,539.0 2,453.0 0.002204 0.006612 5.5960 16.2192 7760 1000 21.7 8.1 455.

N2O 2,539.0 2,453.0 0.0002204 0.001322 0.5596 3.2438 7760 1000 2.2 1.6 673.

Total 1,152,3

Maximum Total 1,300,8

a Table C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtu 

Pollutant Natural Gas Distillate Fuel Oil

CO2 53.02 73.96

CH4 0.001 0.003

N2O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH4 and N2O are multiplied by CO2e factor

Pollutant CO2e Factor

CH4 21

N2O 310

TABLE B-17

SIEMENS H CT, DRY LOW NOx COMBUSTOR, BASE LOAD

Maximum

GREENHOUSE GAS (GHG) EMISSIONS

Heat Input at 75 0F Emission Factor a Hourly GHG Emissions Annual GHG Emissions 

 (MMBtu/hr) (lb/MMBtu) (lb/hr) Operating Hours (TPY)

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Maximum Emission Hourly Annual CO2e 

Emission Unit/ Heat Input Factor a GHG Emissions Operating GHG Emissions Emissions Rate b 

Pollutant (MMBtu/hr) (lb/MMBtu) (lb/hr) Hours (TPY) (TPY)

Emergency Generator (Fuel Oil)

CO2 21.01 163.0 3,424.8 200 342.5 342.5

CH4 21.01 0.006612 0.139 200 0.014 0.29

N2O 21.01 0.001322 0.028 200 0.0028 0.86

343.6

Natural Gas Heater (Natural Gas)

CO2 9.90 116.9 1,156.9 8,760 5,067.1 5067.1

CH4 9.90 0.002204 0.022 8,760 0.096 2.01

N2O 9.90 0.0002204 0.0022 8,760 0.0096 2.96

5,072.1

Fire Pump Engine (Fuel Oil)

CO2 2.32 163.0 378.8 80 15.2 15.2

CH4 2.32 0.006612 0.0154 80 0.00061 0.01

N2O 2.32 0.001322 0.0031 80 0.00012 0.04

15.2

 Gas Compressor (Natural Gas)

CO2 53.98 116.9 6,308.1 8,760 27,629.5 27,629.5

CH4 53.98 0.002204 0.119 8,760 0.521 10.94

N2O 53.98 0.0002204 0.012 8,760 0.0521 16.15

27,656.6

a Table C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtu 

Pollutant Natural Gas Distillate Fuel Oil

CO2 53.02 73.96

CH4 0.001 0.003

N2O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH4 and N2O are multiplied by CO2e factor

Pollutant CO2e Factor

CH4 21

N2O 310

TABLE B-18

GREENHOUSE GAS (GHG) EMISSIONS

FOR ADDITIONAL PEEC EMISSION UNITS

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APPENDIX C 

 
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Maximum

2-Year

2006 2007 2008 2009 Average

Pollutant Unit 2006 2007 2008 2009 2010 2007 2008 2009 2010 (tons/year)

 

 SO2 1 1,290.6 1,436.3 400.7 570.8 11.6 1,363.5 918.5 485.7 291.2

2 1,262.1 1,166.5 719.1 595.9 55.4 1,214.3 942.8 657.5 325.7

3 3,918.1 3,061.8 2,066.4 2,058.7 1,797.6 3,489.9 2,564.1 2,062.6 1,928.2

4 2,616.1 4,237.2 2,182.3 2,159.6 2,002.7 3,426.7 3,209.8 2,171.0 2,081.2

9,086.9 9,901.8 5,368.5 5,385.0 3,867.3 9,494.3 7,635.1 5,376.7 4,626.2 9,494.3

 PM 1 57.4 8.5 59.1 1.1 0.04 33.0 33.8 30.1 0.6

2 9.5 6.5 76.5 19.5 0.5 8.0 41.5 48.0 10.0

3 337.0 337.0 175.1 5.0 1.3 337.0 256.0 90.0 3.1

4 228.9 222.2 136.4 45.2 7.7 225.6 179.3 90.8 26.4

632.8 574.2 447.1 70.8 9.6 603.5 510.7 258.9 40.2 603.5

 PM10 1 57.4 8.5 59.1 1.1 0.04 33.0 33.8 30.1 0.6

2 9.5 6.5 76.5 19.5 0.5 8.0 41.5 48.0 10.0

3 337.0 337.0 175.1 5.0 1.3 337.0 256.0 90.0 3.1

4 228.9 222.2 136.4 45.2 7.7 225.6 179.3 90.8 26.4

632.8 574.2 447.1 70.8 9.6 603.5 510.7 258.9 40.2 603.5

 NOx 1 710.8 428.6 201.8 229.0 11.6 569.7 315.2 215.4 120.3

2 712.6 344.0 280.4 228.5 14.1 528.3 312.2 254.4 121.3

3 2,148.5 1,156.1 1,998.6 1,898.4 1,525.6 1,652.3 1,577.3 1,948.5 1,712.0

4 1,577.5 1,442.9 1,905.0 1,651.8 1,493.8 1,510.2 1,674.0 1,778.4 1,572.8

5,149.3 3,371.5 4,385.8 4,007.8 3,045.1 4,260.4 3,878.7 4,196.8 3,526.5 4,260.4

 CO 1 136.9 74.2 74.2 69.9 1.6 105.6 74.2 72.0 35.7

2 139.2 57.8 94.9 83.6 2.1 98.5 76.4 89.3 42.8

3 412.9 303.8 390.6 320.8 286.0 358.4 347.2 355.7 303.4

4 318.6 326.1 361.8 313.8 228.9 322.4 343.9 337.8 271.3

1,007.6 761.9 921.5 788.0 518.6 884.8 841.7 854.8 653.3 884.8

 VOC 1 10.0 9.0 6.0 6.2 0.2 9.5 7.5 6.1 3.2

(as methane) 2 10.0 7.2 8.2 7.1 0.3 8.6 7.7 7.7 3.7

3 30.2 28.8 31.3 26.3 23.6 29.5 30.0 28.8 25.0

4 21.8 33.6 29.8 26.5 20.3 27.7 31.7 28.1 23.4

72.0 78.6 75.3 66.2 44.5 75.3 76.9 70.7 55.3 76.9

Lead 1 0.013 0.015 0.004 0.006 0.0004 0.014 0.009 0.005 0.003

2 0.013 0.012 0.007 0.006 0.0005 0.012 0.010 0.007 0.003

3 0.040 0.032 0.022 0.020 0.018 0.036 0.027 0.021 0.019

4 0.027 0.044 0.023 0.022 0.020 0.036 0.033 0.023 0.021

0.093 0.103 0.057 0.055 0.039 0.098 0.080 0.056 0.047 0.098

SAM a 1 57.4 63.9 17.8 25.4 0.5 60.6 40.8 21.6 13.0

2 56.1 51.9 32.0 26.5 2.5 54.0 41.9 29.2 14.5

3 174.3 136.2 91.9 91.6 79.9 155.2 114.0 91.7 85.8

4 116.3 188.4 97.1 96.0 89.1 152.4 142.8 96.6 92.6

404.1 440.4 238.8 239.5 172.0 422.3 339.6 239.1 205.7 422.3

a

 Estimated from SO2 emissions and based on ratio of AP-42 emission factors for fuel oil combustion (Table 1.3-1) for SO 3 and SO2. 

 SO3 is assumed to be converted to H 2SO4. 

 SO3 emission factor 5.7 S lb/1000 gal (S = sulfur content)

SO2 emission factor 157 S lb/1000 gal (S = sulfur content)

Ratio SO3/SO2 emissions 0.036 fraction

SO3 molecular wgt (MW) 80

H2SO4 MW 98

Ratio H2SO4/SO2 MW 1.225

Ratio H2SO4/SO2 emissions 0.044

Source: FPL, 2011

TABLE C-1

SUMMARY OF MAXIMUM ANNUAL SO2, PM, NOx, CO, VOC EMISSIONS 

2-Year Average

Annual Emissions (tons/year)

Annual Emissions (tons/year)

FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT USING AOR DATA

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Table C-1 PPE AORsummary
January 2012 

Unit ID

Operating 

Year

Operation Time 

(hrs)

Months 

Reported

Gross Load 

(MWh)

CO2 Emissions 

(TPY)

Heat 

Input(mmBtu) Primary Fuel Secondary F

Unit 1 2010 58.59 12 8,068.30 7,269.89 81,243.34 Residual Oil Pipeline NaturaUnit 2 2010 78.96 12 11,418.42 9,685.68 110,216.93 Residual Oil Pipeline NaturaUnit 3 2010 5,646.15 12 816,717.75 651,953.52 8,671,770.00 Residual Oil Pipeline NaturaUnit 4 2010 4,863.70 12 703,514.81 592,940.71 7,620,377.43 Residual Oil Pipeline NaturaUnit 1 2009 2,352.73 12 218,983.50 176,410.18 2,311,759.73 Residual Oil Pipeline NaturaUnit 2 2009 2,581.57 12 253,878.27 200,338.53 2,657,008.68 Residual Oil Pipeline NaturaUnit 3 2009 5,992.95 12 936,274.52 766,171.73 10,191,575.58 Residual Oil Pipeline NaturaUnit 4 2009 6,051.82 12 915,856.15 748,031.50 9,901,521.02 Residual Oil Pipeline NaturaUnit 1 2008 912.91 5 76,175.22 62,258.08 822,342.76 Residual Oil Pipeline NaturaUnit 2 2008 1,384.32 5 129,071.73 108,435.70 1,387,612.06 Residual Oil Pipeline NaturaUnit 3 2008 3,132.55 5 534,797.16 415,737.09 5,537,674.70 Residual Oil Pipeline NaturaUnit 4 2008 3,245.35 5 605,729.60 468,171.89 6,208,456.77 Residual Oil Pipeline NaturaUnit 1 2007 3,128.77 12 318,360.20 288,111.64 3,393,060.91 Residual Oil Pipeline NaturaUnit 2 2007 2,607.50 12 257,766.53 233,711.48 2,744,636.30 Residual Oil Pipeline NaturaUnit 3 2007 5,573.87 12 1,086,955.26 859,762.61 10,941,432.19 Residual Oil Pipeline NaturaUnit 4 2007 6,414.33 12 1,297,789.65 1,040,523.23 12,857,134.88 Residual Oil Pipeline NaturaUnit 1 2006 3,792.97 12 468,698.42 371,454.59 4,777,247.08 Residual Oil Pipeline NaturaUnit 2 2006 3,826.16 12 464,109.13 370,538.89 4,784,052.94 Residual Oil Pipeline NaturaUnit 3 2006 7,130.62 12 1,393,401.45 1,113,274.71 14,310,310.05 Residual Oil Pipeline NaturaUnit 4 2006 5,234.70 12 1,033,553.37 812,679.47 10,593,474.53 Residual Oil Pipeline Natura

SUMMARY OF CO2 EMISSIONS FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLA

TABLE C-2

BASED ON ACID RAIN PROGRAM DATA

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January 2012 113-87618

Actual

Annual Emission CO2e c Emission CO2e c

Heat Input a Factor b Rate Factor b Rate

Year (MMBtu/yr) (lb/MMBtu) (lb/yr) (TPY) (TPY) (lb/MMBtu) (lb/yr) (TPY) (TPY)

No.6 Fuel Oil

2010 7,386,440 1.32E-03 9,767.8 4.9 1,514.0 6.6E-03 48,839.1 24.4 512.8

2009 10,249,512 1.32E-03 13,554.0 6.8 2,100.9 6.6E-03 67,769.8 33.9 711.6

2008 10,489,520 1.32E-03 13,871.3 6.9 2,150.1 6.6E-03 69,356.7 34.7 728.2

2007 20,175,720 1.32E-03 26,680.4 13.3 4,135.5 6.6E-03 133,401.9 66.7 1,400.7

2006 17,944,056 1.32E-03 23,729.2 11.9 3,678.0 6.6E-03 118,646.1 59.3 1,245.8

Natural Gas

2010 9,454,000 2.20E-04 2,083.7 1.042 323.0 2.2E-03 20,836.6 10.418 218.8

2009 14,748,000 2.20E-04 3,250.5 1.625 503.8 2.2E-03 32,504.6 16.252 341.3

2008 17,833,000 2.20E-04 3,930.4 1.965 609.2 2.2E-03 39,303.9 19.652 412.7

2007 10,239,000 2.20E-04 2,256.7 1.128 349.8 2.2E-03 22,566.8 11.283 237.0

2006 16,955,000 2.20E-04 3,736.9 1.868 579.2 2.2E-03 37,368.8 18.684 392.4

LPG

2010 365 1.32E-03 0.5 0.0 0.1 6.6E-03 2.4 0.0 0.0

2009 669 1.32E-03 0.9 0.0 0.1 6.6E-03 4.4 0.0 0.0

2008 684 1.32E-03 0.9 0.0 0.1 6.6E-03 4.5 0.0 0.0

2007 706 1.32E-03 0.9 0.0 0.1 6.6E-03 4.7 0.0 0.0

2006 604 1.32E-03 0.8 0.0 0.1 6.6E-03 4.0 0.0 0.0

Total

2010 -- -- -- 5.9 1,837.1 -- -- 34.8 731.6

2009 -- -- -- 8.4 2,604.8 -- -- 50.1 1,052.9

2008 -- -- -- 8.9 2,759.4 -- -- 54.3 1,141.0

2007 -- -- -- 14.5 4,485.4 -- -- 78.0 1,637.7

2006 -- -- -- 13.7 4,257.4 -- -- 78.0 1,638.2

a Based on AOR data for the period 2006-2010 shown below: 

No.6 Fuel Oil Unit 1 Unit 2 Unit 3 Unit 4

2010 79,040 107,160 3,442,800 3,757,440 7,386,440

2009 1,117,048 1,174,352 3,743,760 4,214,352 10,249,512

2008 782,800 1,405,392 4,037,120 4,264,208 10,489,520

2007 2,927,064 2,377,280 6,237,624 8,633,752 20,175,720

2006 2,548,736 2,492,344 7,737,408 5,165,568 17,944,056

Natural Gas

2010 7,000 7,000 5,461,000 3,979,000 9,454,000

2009 1,226,000 1,530,000 6,172,000 5,820,000 14,748,000

2008 1,460,000 1,710,000 7,720,000 6,943,000 17,833,000

2007 620,000 445,000 4,790,000 4,384,000 10,239,000

2006 2,261,000 2,336,000 6,798,000 5,560,000 16,955,000

LPG

2010 2 2 183 178 365

2009 72 74 260 263 669

2008 81 113 250 240 684

2007 115 99 219 274 706

2006 121 124 359 0 604

b Table C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtu 

Pollutant No.6.Fuel Oil Natural Gas LPG

CH4 0.003 0.001 0.003

N2O 0.0006 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

c N2O and CH4 emissions are multiplied by CO2e factor

Pollutant CO2e Factor

N2O 310

CH4 21

Heat Input (MMBtu) Total

TABLE C-3

ESTIMATED ANNUAL EMISSIONS OF N2O AND CH4

FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT USING AOR DATA

N2O Emissions CH4 Emissions

Annual Emissions Annual Emissions

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Table C-3 PPE N2O&CH4
January 2012 

2006 2007 2008 

Pollutant Unit 2006 2007 2008 2009 2010 2007 2008 2009 

 CO2a 1 371,454.6 288,111.6 62,258.1 176,410.2 7,269.9 329,783.1 175,184.9 119,334.1 

2 370,538.9 233,711.5 108,435.7 200,338.5 9,685.7 302,125.2 171,073.6 154,387.1 3 1,113,274.7 859,762.6 415,737.1 766,171.7 651,953.5 986,518.7 637,749.9 590,954.4 74 812,679.5 1,040,523.2 468,171.9 748,031.5 592,940.7 926,601.3 754,347.6 608,101.7 

2,667,947.7 2,422,109.0 1,054,602.8 1,890,951.9 1,261,849.8 2,545,028.3 1,738,355.9 1,472,777.4 1

N2Ob 4,257.4 4,485.4 2,759.4 2,604.8 1,837.1 4,371.4 3,622.4 2,682.1 

CH4b 1,638.2 1,637.7 1,141.0 1,052.9 731.6 1,638.0 1,389.4 1,097.0 

a Annual Emissions based on CEMS data obtained from EPA Acid Rain database.b N2O and CH4 emissions based on actual annual heat input from Annual Operating Reports

Source: FPL, 2011

TABLE C-4

SUMMARY OF MAXIMUM ANNUAL GHG EMISSIONS FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES 

2-Year Average

Annual CO2e Emissions (TPY)

Annual CO2 Equivalent Emissions (TPY)

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Table C4 PPE GHG SUM
APPENDIX D 

 
January 2012 113-87618 

Figure D-1 

Receptor Grid Used in Air Modeling Analyses for PEEC 

Source: Golder, 2011. 

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January 2012 113-87618 

Figure D-2 

Source and Building Locations for PEEC 

Source: Golder, 2011. 

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Appendix D-2.docx 
APPENDIX E 

 
CO STARTING

 TITLEONE 2006 FPL PPE NEW CTS - CT LOAD ANALYSIS, MHI "J" CLASS GAS 9/13/11

 TITLETWO GENERIC (10 g/s) EMISSION RATES FOR CC CTS

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 24 8 3 1

 POLLUTID GEN

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION GA1095 POINT 587489.306 2885478.742 0.000

 LOCATION GB1095 POINT 587443.291 2885477.412 0.000

 LOCATION GC1095 POINT 587349.178 2885474.119 0.000

 LOCATION GA1075 POINT 587489.306 2885478.742 0.000

 LOCATION GB1075 POINT 587443.291 2885477.412 0.000

 LOCATION GC1075 POINT 587349.178 2885474.119 0.000

 LOCATION GA1035 POINT 587489.306 2885478.742 0.000

 LOCATION GB1035 POINT 587443.291 2885477.412 0.000

 LOCATION GC1035 POINT 587349.178 2885474.119 0.000

 LOCATION GA7595 POINT 587489.306 2885478.742 0.000

 LOCATION GB7595 POINT 587443.291 2885477.412 0.000

 LOCATION GC7595 POINT 587349.178 2885474.119 0.000

 LOCATION GA7575 POINT 587489.306 2885478.742 0.000

 LOCATION GB7575 POINT 587443.291 2885477.412 0.000

 LOCATION GC7575 POINT 587349.178 2885474.119 0.000

 LOCATION GA7535 POINT 587489.306 2885478.742 0.000

 LOCATION GB7535 POINT 587443.291 2885477.412 0.000

 LOCATION GC7535 POINT 587349.178 2885474.119 0.000

 LOCATION GA5095 POINT 587489.306 2885478.742 0.000

 LOCATION GB5095 POINT 587443.291 2885477.412 0.000

 LOCATION GC5095 POINT 587349.178 2885474.119 0.000

 LOCATION GA5075 POINT 587489.306 2885478.742 0.000

 LOCATION GB5075 POINT 587443.291 2885477.412 0.000

 LOCATION GC5075 POINT 587349.178 2885474.119 0.000

 LOCATION GA5035 POINT 587489.306 2885478.742 0.000

 LOCATION GB5035 POINT 587443.291 2885477.412 0.000

 LOCATION GC5035 POINT 587349.178 2885474.119 0.000

** Source Parameters **
** Baseload, 95 F

 SRCPARAM GA1095 3.3333 45.4 363.7 16.86 6.71

 SRCPARAM GB1095 3.3333 45.4 363.7 16.86 6.71

 SRCPARAM GC1095 3.3333 45.4 363.7 16.86 6.71

** Baseload, 75 F

 SRCPARAM GA1075 3.3333 45.4 363.7 17.47 6.71

 SRCPARAM GB1075 3.3333 45.4 363.7 17.47 6.71

 SRCPARAM GC1075 3.3333 45.4 363.7 17.47 6.71

** Baseload, 35 F

 SRCPARAM GA1035 3.3333 45.4 364.3 18.61 6.71

 SRCPARAM GB1035 3.3333 45.4 364.3 18.61 6.71

 SRCPARAM GC1035 3.3333 45.4 364.3 18.61 6.71

** 75% Load, 95 F

 SRCPARAM GA7595 3.3333 45.4 359.3 13.48 6.71

 SRCPARAM GB7595 3.3333 45.4 359.3 13.48 6.71

 SRCPARAM GC7595 3.3333 45.4 359.3 13.48 6.71

** 75% Load, 75 F

 SRCPARAM GA7575 3.3333 45.4 358.7 13.96 6.71

 SRCPARAM GB7575 3.3333 45.4 358.7 13.96 6.71

 SRCPARAM GC7575 3.3333 45.4 358.7 13.96 6.71

** 75% Load, 35 F

 SRCPARAM GA7535 3.3333 45.4 357.6 14.99 6.71

 SRCPARAM GB7535 3.3333 45.4 357.6 14.99 6.71

 SRCPARAM GC7535 3.3333 45.4 357.6 14.99 6.71

** 50% Load, 95 F

 SRCPARAM GA5095 3.3333 45.4 359.3 11.18 6.71

 SRCPARAM GB5095 3.3333 45.4 359.3 11.18 6.71

 SRCPARAM GC5095 3.3333 45.4 359.3 11.18 6.71

** 50% Load, 75 F

 SRCPARAM GA5075 3.3333 45.4 358.7 11.39 6.71

 SRCPARAM GB5075 3.3333 45.4 358.7 11.39 6.71

 SRCPARAM GC5075 3.3333 45.4 358.7 11.39 6.71

** 50% Load, 35 F

 SRCPARAM GA5035 3.3333 45.4 357.6 11.80 6.71

 SRCPARAM GB5035 3.3333 45.4 357.6 11.80 6.71

 SRCPARAM GC5035 3.3333 45.4 357.6 11.80 6.71

** Building Downwash **

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59
SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ GA1035-GA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ GA1035-GA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ GA1035-GA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ GA1035-GA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ GA1035-GA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ GA1035-GA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ GA1035-GA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ GA1035-GA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ GA1035-GA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ GA1035-GA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ GA1035-GA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ GA1035-GA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ GB1035-GB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ GB1035-GB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ GB1035-GB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ GB1035-GB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ GB1035-GB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ GB1035-GB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ GB1035-GB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ GB1035-GB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ GB1035-GB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ GB1035-GB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ GB1035-GB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ GB1035-GB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56
SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ GC1035-GC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ GC1035-GC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ GC1035-GC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ GC1035-GC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ GC1035-GC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ GC1035-GC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ GC1035-GC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ GC1035-GC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ GC1035-GC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ GC1035-GC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ GC1035-GC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ GC1035-GC7595 14.74 12.05 8.99 5.66 2.16 -1.41

 SRCGROUP G1095 GA1095 GB1095 GC1095

 SRCGROUP G1075 GA1075 GB1075 GC1075

 SRCGROUP G1035 GA1035 GB1035 GC1035

 SRCGROUP G7595 GA7595 GB7595 GC7595

 SRCGROUP G7575 GA7575 GB7575 GC7575

 SRCGROUP G7535 GA7535 GB7535 GC7535

 SRCGROUP G5095 GA5095 GB5095 GC5095

 SRCGROUP G5075 GA5075 GB5075 GC5075

 SRCGROUP G5035 GA5035 GB5035 GC5035

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED

**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M2006.SFC

 PROFFILE s:\amodmet\FLL1M2006.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP
 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE FIRST

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :gengas.o06

AERMOD OUTPUT FILE NUMBER 2 :gengas.o07

AERMOD OUTPUT FILE NUMBER 3 :gengas.o08

AERMOD OUTPUT FILE NUMBER 4 :gengas.o09

AERMOD OUTPUT FILE NUMBER 5 :gengas.o10

First title for last output file is: 2006 FPL PPE NEW CTS - CT LOAD ANALYSIS, MHI 

"J" CLASS GAS 9/13/11

Second title for last output file is: GENERIC (10 g/s) EMISSION RATES FOR CC CTS

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: G1095

Annual

 06 0.43860 586800.0 2885800.0 06123124

 07 0.42699 586700.0 2885400.0 07123124

08 0.47887 586800.0 2885900.0 08123124

09 0.57469 586900.0 2885900.0 09123124

10 0.43899 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 3.89602 586300. 2884900. 06110424

07 5.23999 586400. 2884900. 07103024

08 4.56985 586300. 2885700. 08090924

09 3.71606 586000. 2885300. 09110824

10 3.30113 586600. 2885300. 10062424

HIGH 8-Hour

 06 7.22551 586800. 2885200. 06101516

07 8.45774 586300. 2884800. 07103024

08 7.21284 586100. 2885600. 08090908

09 7.28918 586700. 2885400. 09042616

10 7.59978 586700. 2885500. 10051216

HIGH 3-Hour

 06 7.69102 586700. 2885300. 06100312

07 9.13692 586300. 2884800. 07103021

08 8.20163 586100. 2885600. 08090906

09 8.29798 586700. 2885600. 09081612

10 8.03552 586700. 2885600. 10072012

HIGH 1-Hour

 06 9.51961 586500. 2885000. 06110404

07 9.50006 586500. 2884900. 07103019

08 8.69335 588100. 2885600. 08051211

09 8.71712 586800. 2885600. 09081610

10 8.23403 586700. 2885400. 10071712

SOURCE GROUP ID: G1075

Annual

 06 0.42420 586800.0 2885800.0 06123124

07 0.41305 586700.0 2885400.0 07123124

08 0.46490 586800.0 2885900.0 08123124

 09 0.55926 586900.0 2885900.0 09123124

 10 0.42456 586900.0 2885900.0 10123124
HIGH 24-Hour

 06 3.71332 586300. 2884900. 06110424

 07 5.05629 586400. 2884900. 07103024

 08 4.36522 586300. 2885700. 08090924

09 3.52397 586000. 2885300. 09110824

10 3.21649 586600. 2885300. 10062424

HIGH 8-Hour

 06 7.00401 586800. 2885200. 06101516

07 8.23864 586300. 2884800. 07103024

08 6.99049 586800. 2885400. 08050116

09 7.09047 586700. 2885400. 09042616

10 7.39271 586700. 2885500. 10051216

HIGH 3-Hour

 06 7.51820 586700. 2885300. 06100312

07 8.84378 586300. 2884800. 07103021

08 7.86908 586100. 2885600. 08090906

09 8.11585 586700. 2885600. 09081612

10 7.85943 586700. 2885600. 10072012

HIGH 1-Hour

 06 9.17046 586400. 2884900. 06110404

07 9.25428 586500. 2884900. 07103018

08 8.47975 588100. 2885600. 08051211

09 8.49000 586800. 2885600. 09081610

10 8.04296 586700. 2885400. 10071712

SOURCE GROUP ID: G1035

Annual

 06 0.39699 586800.0 2885800.0 06123124

07 0.38720 586700.0 2885400.0 07123124

08 0.43852 586800.0 2885900.0 08123124

09 0.52999 586900.0 2885900.0 09123124

10 0.39738 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 3.40661 586500. 2885000. 06110424

07 4.65992 586400. 2884900. 07103024

08 3.98716 586300. 2885700. 08090924

09 3.17840 585900. 2885300. 09110824

 10 3.05384 586600. 2885300. 10062424

HIGH 8-Hour

 06 6.57713 586800. 2885200. 06101516

07 7.70974 586300. 2884800. 07103024

 08 6.58265 586800. 2885400. 08050116

 09 6.78094 586700. 2885400. 09042616

10 6.99890 586700. 2885500. 10051216

HIGH 3-Hour

 06 7.18258 586700. 2885300. 06100312

 07 8.29659 586300. 2884800. 07103021

08 7.33153 587000. 2886000. 08051615

09 7.76518 586700. 2885600. 09081612

10 7.52347 586700. 2885600. 10072012

HIGH 1-Hour

 06 9.36765 586500. 2885000. 06110404

07 8.75899 586500. 2884900. 07103019

08 8.05387 588100. 2885600. 08051211

09 8.02966 586800. 2885600. 09081610
 10 7.67711 586700. 2885400. 10071712

SOURCE GROUP ID: G7595

Annual

 06 0.56024 586800.0 2885800.0 06123124

07 0.54954 586700.0 2885400.0 07123124

08 0.59943 586900.0 2885800.0 08123124

09 0.70829 586900.0 2885800.0 09123124

10 0.55829 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 5.46558 586500. 2885000. 06110424

07 7.02122 586400. 2884900. 07103024

08 6.19516 586600. 2885600. 08090924

09 5.55908 586300. 2885400. 09110824

10 4.14089 586700. 2885500. 10051224

HIGH 8-Hour

 06 9.16828 586800. 2885200. 06101516

07 10.69136 586500. 2884900. 07103024

08 9.84355 586300. 2885600. 08090908

09 9.25542 586800. 2885700. 09110916

10 9.53319 586800. 2885500. 10051216

HIGH 3-Hour

 06 9.64827 586800. 2885400. 06082912

07 11.50433 586500. 2884900. 07103021

08 10.89372 586200. 2885600. 08090906

 09 9.95692 586800. 2885600. 09081612

 10 10.06277 586700. 2885600. 10072012

HIGH 1-Hour

 06 11.47423 586500. 2885000. 06110404

 07 11.92211 586500. 2884900. 07103019

 08 11.22940 586300. 2885600. 08090905

09 10.73468 586800. 2885600. 09081610

10 10.37696 586800. 2885400. 10092311

SOURCE GROUP ID: G7575

Annual

 06 0.54579 586800.0 2885800.0 06123124

07 0.53362 586700.0 2885400.0 07123124

 08 0.58361 586900.0 2885800.0 08123124

 09 0.69248 586900.0 2885800.0 09123124

10 0.54432 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 5.24376 586500. 2885000. 06110424

07 6.79670 586400. 2884900. 07103024

08 6.00139 586400. 2885700. 08090924

09 5.32376 586300. 2885400. 09110824

10 4.00897 586700. 2885500. 10051224

HIGH 8-Hour

 06 8.87215 586800. 2885200. 06101516

07 10.41849 586500. 2884900. 07103024

08 9.56184 586300. 2885600. 08090908

09 8.96708 586800. 2885700. 09110916

10 9.20736 586800. 2885500. 10051216

HIGH 3-Hour

 06 9.27919 586800. 2885400. 06082912

07 11.21980 586500. 2884900. 07103021
 08 10.58833 586200. 2885600. 08090906

09 9.70577 586700. 2885600. 09081612

10 9.79601 586700. 2885600. 10072012

HIGH 1-Hour

 06 11.22766 586500. 2885000. 06110404

07 11.67209 586500. 2884900. 07103019

08 10.89030 586300. 2885600. 08090905

09 10.41761 586800. 2885600. 09081610

 10 10.02430 586800. 2885400. 10092311

SOURCE GROUP ID: G7535

Annual

 06 0.51747 586800.0 2885800.0 06123124

07 0.50297 586700.0 2885400.0 07123124

08 0.55398 586800.0 2885900.0 08123124

09 0.66090 586900.0 2885800.0 09123124

10 0.51651 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 4.85514 586300. 2884900. 06110424

07 6.34319 586400. 2884900. 07103024

08 5.58536 586400. 2885700. 08090924

09 4.83389 586300. 2885400. 09110824

10 3.76868 586700. 2885500. 10051224

HIGH 8-Hour

 06 8.31871 586800. 2885200. 06101516

07 9.88020 586500. 2884900. 07103024

08 8.91975 586200. 2885600. 08090908

09 8.30375 586700. 2885400. 09042616

10 8.62793 586700. 2885500. 10051216

HIGH 3-Hour

 06 8.74260 586800. 2885300. 06060712

07 10.59763 586500. 2884900. 07103021

08 9.94953 586200. 2885600. 08090906

09 9.24235 586700. 2885600. 09081612

10 9.24673 586700. 2885600. 10072012

HIGH 1-Hour

 06 10.60278 586500. 2885000. 06110404

07 11.10933 586500. 2884900. 07103019

08 10.22846 586200. 2885600. 08090905

09 9.90441 588000. 2885300. 09062210

10 9.36728 586800. 2885200. 10072211

SOURCE GROUP ID: G5095

Annual

 06 0.66647 586900.0 2885800.0 06123124

07 0.66399 586800.0 2885400.0 07123124

08 0.71734 586900.0 2885800.0 08123124

09 0.82189 586900.0 2885800.0 09123124

10 0.66044 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 6.88299 586500. 2885000. 06110424

07 8.65473 586600. 2885000. 07103024

08 7.54516 586700. 2885600. 08090924

09 7.12005 586400. 2885400. 09110824

10 5.07750 586800. 2885500. 10051224

HIGH 8-Hour
 06 11.02324 586800. 2885200. 06101516

07 12.31041 586500. 2884900. 07103024

08 11.70751 586800. 2885600. 08090916

09 11.08582 586800. 2885400. 09110816

10 11.44788 586800. 2885500. 10051216

HIGH 3-Hour

 06 11.81290 586800. 2885400. 06082912

07 13.24091 586500. 2884900. 07103021

08 12.49139 586300. 2885600. 08090906

09 11.75255 587924. 2885138. 09020315

10 11.81720 586800. 2885600. 10072012

HIGH 1-Hour

 06 13.12006 586500. 2885000. 06110404

07 13.45920 586500. 2884900. 07103019

08 12.86591 586900. 2885600. 08070910

09 12.68943 586800. 2885600. 09081609

10 12.40363 586800. 2885400. 10092311

SOURCE GROUP ID: G5075

Annual

 06 0.65815 586900.0 2885800.0 06123124

07 0.65445 586700.0 2885400.0 07123124

08 0.70786 586900.0 2885800.0 08123124

09 0.81330 586900.0 2885800.0 09123124

10 0.65252 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 6.76941 586500. 2885000. 06110424

07 8.52130 586600. 2885000. 07103024

08 7.42183 586700. 2885600. 08090924

09 7.01875 586400. 2885400. 09110824

10 4.99538 586800. 2885500. 10051224

HIGH 8-Hour

 06 10.87889 586800. 2885200. 06101516

07 12.20136 586500. 2884900. 07103024

08 11.55586 586800. 2885600. 08090916

09 10.93816 586800. 2885700. 09110916

10 11.29406 586800. 2885500. 10051216

HIGH 3-Hour

 06 11.64488 586800. 2885400. 06082912

07 13.12542 586500. 2884900. 07103021

08 12.36836 586300. 2885600. 08090906

09 11.58261 587924. 2885138. 09020315

10 11.66293 586800. 2885600. 10072012

HIGH 1-Hour

 06 13.00634 586500. 2885000. 06110404

 07 13.35840 586500. 2884900. 07103019

08 12.64602 586900. 2885600. 08070910

09 12.52888 586800. 2885600. 09081609

10 12.24167 586800. 2885400. 10092311

SOURCE GROUP ID: G5035

Annual

 06 0.64256 586900.0 2885800.0 06123124

 07 0.63742 586700.0 2885400.0 07123124

 08 0.69009 586900.0 2885800.0 08123124

09 0.79736 586900.0 2885800.0 09123124
 10 0.63798 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 6.60949 586500. 2885000. 06110424

07 8.29133 586600. 2885000. 07103024

08 7.20016 586600. 2885600. 08090924

09 6.89112 586400. 2885400. 09110824

10 4.84105 586800. 2885500. 10051224

HIGH 8-Hour

 06 10.60181 586800. 2885200. 06101516

07 11.98552 586500. 2884900. 07103024

08 11.23141 586800. 2885600. 08090916

09 10.68038 586800. 2885700. 09110916

10 11.00006 586800. 2885500. 10051216

HIGH 3-Hour

 06 11.32301 586800. 2885400. 06082912

07 12.89983 586500. 2884900. 07103021

08 12.10100 586300. 2885600. 08090906

09 11.25941 586800. 2885600. 09081612

10 11.36777 586800. 2885500. 10051215

HIGH 1-Hour

 06 12.80719 586500. 2885000. 06110404

07 13.15921 586500. 2884900. 07103019

08 12.36087 586300. 2885600. 08090903

 09 12.44958 586400. 2885400. 09110822

 10 11.93105 586800. 2885400. 10092311

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
CO STARTING

 TITLEONE 2006 FPL PPE NEW CTS - CT LOAD ANALYSIS, MHI "J" CLASS OIL 9/13/11

 TITLETWO GENERIC (10 g/s) EMISSION RATES FOR CC CTS

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 24 8 3 1

 POLLUTID GEN

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION OA1095 POINT 587489.306 2885478.742 0.000

 LOCATION OB1095 POINT 587443.291 2885477.412 0.000

 LOCATION OC1095 POINT 587349.178 2885474.119 0.000

 LOCATION OA1075 POINT 587489.306 2885478.742 0.000

 LOCATION OB1075 POINT 587443.291 2885477.412 0.000

 LOCATION OC1075 POINT 587349.178 2885474.119 0.000

 LOCATION OA1035 POINT 587489.306 2885478.742 0.000

 LOCATION OB1035 POINT 587443.291 2885477.412 0.000

 LOCATION OC1035 POINT 587349.178 2885474.119 0.000

 LOCATION OA7595 POINT 587489.306 2885478.742 0.000

 LOCATION OB7595 POINT 587443.291 2885477.412 0.000

 LOCATION OC7595 POINT 587349.178 2885474.119 0.000

 LOCATION OA7575 POINT 587489.306 2885478.742 0.000

 LOCATION OB7575 POINT 587443.291 2885477.412 0.000

 LOCATION OC7575 POINT 587349.178 2885474.119 0.000

 LOCATION OA7535 POINT 587489.306 2885478.742 0.000

 LOCATION OB7535 POINT 587443.291 2885477.412 0.000

 LOCATION OC7535 POINT 587349.178 2885474.119 0.000

 LOCATION OA5095 POINT 587489.306 2885478.742 0.000

 LOCATION OB5095 POINT 587443.291 2885477.412 0.000

 LOCATION OC5095 POINT 587349.178 2885474.119 0.000

 LOCATION OA5075 POINT 587489.306 2885478.742 0.000

 LOCATION OB5075 POINT 587443.291 2885477.412 0.000

 LOCATION OC5075 POINT 587349.178 2885474.119 0.000

 LOCATION OA5035 POINT 587489.306 2885478.742 0.000

 LOCATION OB5035 POINT 587443.291 2885477.412 0.000

 LOCATION OC5035 POINT 587349.178 2885474.119 0.000

** Source Parameters **
** Baseload, 95 F

 SRCPARAM OA1095 3.3333 45.4 452.0 20.71 6.71

 SRCPARAM OB1095 3.3333 45.4 452.0 20.71 6.71

 SRCPARAM OC1095 3.3333 45.4 452.0 20.71 6.71

** Baseload, 75 F

 SRCPARAM OA1075 3.3333 45.4 452.6 21.60 6.71

 SRCPARAM OB1075 3.3333 45.4 452.6 21.60 6.71

 SRCPARAM OC1075 3.3333 45.4 452.6 21.60 6.71

** Baseload, 35 F

 SRCPARAM OA1035 3.3333 45.4 454.8 23.51 6.71

 SRCPARAM OB1035 3.3333 45.4 454.8 23.51 6.71

 SRCPARAM OC1035 3.3333 45.4 454.8 23.51 6.71

** 75% Load, 95 F

 SRCPARAM OA7595 3.3333 45.4 452.0 16.93 6.71

 SRCPARAM OB7595 3.3333 45.4 452.0 16.93 6.71

 SRCPARAM OC7595 3.3333 45.4 452.0 16.93 6.71

** 75% Load, 75 F

 SRCPARAM OA7575 3.3333 45.4 452.6 17.70 6.71

 SRCPARAM OB7575 3.3333 45.4 452.6 17.70 6.71

 SRCPARAM OC7575 3.3333 45.4 452.6 17.70 6.71

** 75% Load, 35 F

 SRCPARAM OA7535 3.3333 45.4 454.8 19.17 6.71

 SRCPARAM OB7535 3.3333 45.4 454.8 19.17 6.71

 SRCPARAM OC7535 3.3333 45.4 454.8 19.17 6.71

** 50% Load, 95 F

 SRCPARAM OA5095 3.3333 45.4 452.0 14.58 6.71

 SRCPARAM OB5095 3.3333 45.4 452.0 14.58 6.71

 SRCPARAM OC5095 3.3333 45.4 452.0 14.58 6.71

** 50% Load, 75 F

 SRCPARAM OA5075 3.3333 45.4 452.6 15.20 6.71

 SRCPARAM OB5075 3.3333 45.4 452.6 15.20 6.71

 SRCPARAM OC5075 3.3333 45.4 452.6 15.20 6.71

** 50% Load, 35 F

 SRCPARAM OA5035 3.3333 45.4 454.8 16.37 6.71

 SRCPARAM OB5035 3.3333 45.4 454.8 16.37 6.71

 SRCPARAM OC5035 3.3333 45.4 454.8 16.37 6.71

** Building Downwash **

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59
SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ OA1035-OA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ OA1035-OA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ OA1035-OA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ OA1035-OA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ OA1035-OA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ OA1035-OA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ OA1035-OA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ OA1035-OA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ OA1035-OA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ OA1035-OA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ OA1035-OA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ OA1035-OA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ OB1035-OB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ OB1035-OB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ OB1035-OB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ OB1035-OB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ OB1035-OB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ OB1035-OB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ OB1035-OB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ OB1035-OB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ OB1035-OB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ OB1035-OB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ OB1035-OB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ OB1035-OB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56
SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ OC1035-OC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ OC1035-OC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ OC1035-OC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ OC1035-OC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ OC1035-OC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ OC1035-OC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ OC1035-OC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ OC1035-OC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ OC1035-OC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ OC1035-OC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ OC1035-OC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ OC1035-OC7595 14.74 12.05 8.99 5.66 2.16 -1.41

 SRCGROUP O1095 OA1095 OB1095 OC1095

 SRCGROUP O1075 OA1075 OB1075 OC1075

 SRCGROUP O1035 OA1035 OB1035 OC1035

 SRCGROUP O7595 OA7595 OB7595 OC7595

 SRCGROUP O7575 OA7575 OB7575 OC7575

 SRCGROUP O7535 OA7535 OB7535 OC7535

 SRCGROUP O5095 OA5095 OB5095 OC5095

 SRCGROUP O5075 OA5075 OB5075 OC5075

 SRCGROUP O5035 OA5035 OB5035 OC5035

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED

**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M2006.SFC

 PROFFILE s:\amodmet\FLL1M2006.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP
 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE FIRST

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :genoil.o06

AERMOD OUTPUT FILE NUMBER 2 :genoil.o07

AERMOD OUTPUT FILE NUMBER 3 :genoil.o08

AERMOD OUTPUT FILE NUMBER 4 :genoil.o09

AERMOD OUTPUT FILE NUMBER 5 :genoil.o10

First title for last output file is: 2006 FPL PPE NEW CTS - CT LOAD ANALYSIS, 

MHI "J" CLASS OIL 9/13/11

Second title for last output file is: GENERIC (10 g/s) EMISSION RATES FOR CC 

CTS

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: O1095

Annual

 06 0.21064 586800.0 2885800.0 06123124

 07 0.21514 586600.0 2885400.0 07123124

08 0.24948 586800.0 2885900.0 08123124

09 0.31877 586800.0 2885900.0 09123124

10 0.21481 586800.0 2886000.0 10123124

HIGH 24-Hour

 06 1.78851 586300. 2884900. 06110424

07 2.42035 586300. 2884800. 07103024

08 1.97808 586400. 2885700. 08090924

09 2.04834 586600. 2885400. 09042624

10 1.81373 586500. 2885300. 10062424

HIGH 8-Hour

 06 3.96968 586500. 2885000. 06110416

07 4.06775 586600. 2885300. 07032616

08 4.23897 586600. 2885800. 08083116

09 4.64794 586600. 2885400. 09042616

10 4.19013 586600. 2885500. 10051216

HIGH 3-Hour

 06 4.45345 586700. 2885300. 06100312

07 4.52250 586600. 2885300. 07100615

08 4.80044 586600. 2885800. 08083115

09 4.99484 586700. 2885400. 09042612

10 4.87550 586700. 2885600. 10072012

HIGH 1-Hour

 06 5.03192 586700. 2885400. 06082912

07 4.93308 586600. 2885300. 07052511

08 5.08336 588100. 2885600. 08051212

09 5.24870 588200. 2885700. 09030114

10 5.02790 586700. 2885600. 10072012

SOURCE GROUP ID: O1075

Annual

 06 0.20087 586800.0 2885800.0 06123124

07 0.20546 586600.0 2885400.0 07123124

08 0.23886 586800.0 2885900.0 08123124

 09 0.30687 586800.0 2885900.0 09123124

 10 0.20523 586800.0 2886000.0 10123124
HIGH 24-Hour

 06 1.69922 586300. 2884900. 06110424

 07 2.26663 586300. 2884800. 07103024

 08 1.89437 586400. 2885700. 08090924

09 1.98160 586600. 2885400. 09042624

10 1.74382 586500. 2885300. 10062424

HIGH 8-Hour

 06 3.84493 586500. 2885000. 06110416

07 3.91474 586600. 2885300. 07032616

08 4.08492 586600. 2885800. 08083116

09 4.50257 586600. 2885400. 09042616

10 4.02154 586600. 2885500. 10051216

HIGH 3-Hour

 06 4.28569 586600. 2885000. 06041115

07 4.34802 586600. 2885300. 07100615

08 4.65365 586600. 2885800. 08083115

09 4.82459 586700. 2885400. 09042612

10 4.69145 586600. 2885600. 10072012

HIGH 1-Hour

 06 4.82715 586700. 2885400. 06082912

07 4.77384 586600. 2885300. 07052511

08 4.88367 588100. 2885600. 08051212

09 5.09399 588200. 2885700. 09030114

10 4.85012 586700. 2885600. 10072012

SOURCE GROUP ID: O1035

Annual

 06 0.18179 586700.0 2885800.0 06123124

07 0.18618 586600.0 2885400.0 07123124

08 0.21767 586800.0 2885900.0 08123124

09 0.28287 586800.0 2885900.0 09123124

10 0.18618 586800.0 2886000.0 10123124

HIGH 24-Hour

 06 1.52767 586300. 2884900. 06110424

07 1.98265 586100. 2884700. 07103024

08 1.75661 586400. 2885700. 08090924

09 1.84387 586600. 2885400. 09042624

 10 1.60212 586500. 2885300. 10062424

HIGH 8-Hour

 06 3.59302 586500. 2885000. 06110416

07 3.60187 586600. 2885300. 07032616

 08 3.80559 586400. 2885700. 08090916

 09 4.20144 586600. 2885400. 09042616

10 3.68124 586600. 2885500. 10051216

HIGH 3-Hour

 06 4.03213 586600. 2885000. 06041115

 07 3.99553 586600. 2885300. 07100615

08 4.34712 586600. 2885800. 08083115

09 4.47909 586700. 2885400. 09042612

10 4.32034 586600. 2885600. 10072012

HIGH 1-Hour

 06 4.40938 586700. 2885400. 06082912

07 4.43980 586600. 2885300. 07052511

08 4.52587 586700. 2885700. 08083113

09 4.77711 588200. 2885700. 09030114
 10 4.48847 586700. 2885600. 10072012

SOURCE GROUP ID: O7595

Annual

 06 0.26011 586800.0 2885800.0 06123124

07 0.26316 586600.0 2885400.0 07123124

08 0.30196 586800.0 2885900.0 08123124

09 0.37812 586900.0 2885900.0 09123124

10 0.26313 586800.0 2885900.0 10123124

HIGH 24-Hour

 06 2.32923 586500. 2885000. 06110424

07 3.18228 586300. 2884800. 07103024

08 2.54712 586300. 2885700. 08090924

09 2.37183 586600. 2885400. 09042624

10 2.16940 586600. 2885300. 10062424

HIGH 8-Hour

 06 4.73479 586700. 2885300. 06100316

07 5.05809 586300. 2884800. 07103024

08 5.12526 586500. 2885700. 08090916

09 5.38748 586700. 2885400. 09042616

10 5.05835 586700. 2885500. 10051216

HIGH 3-Hour

 06 5.34530 586700. 2885300. 06100312

07 5.51853 586200. 2884700. 07103021

08 5.51108 586700. 2885500. 08083015

 09 5.86934 586700. 2885600. 09081612

 10 5.76959 586700. 2885600. 10072012

HIGH 1-Hour

 06 6.14195 586300. 2884900. 06110404

 07 6.17375 586300. 2884800. 07103019

 08 6.05328 588100. 2885600. 08051212

09 6.03775 588200. 2885700. 09030114

10 5.83755 586700. 2885600. 10072012

SOURCE GROUP ID: O7575

Annual

 06 0.24792 586800.0 2885800.0 06123124

07 0.25140 586600.0 2885400.0 07123124

 08 0.28914 586800.0 2885900.0 08123124

 09 0.36373 586900.0 2885900.0 09123124

10 0.25115 586800.0 2885900.0 10123124

HIGH 24-Hour

 06 2.18589 586500. 2885000. 06110424

07 2.99772 586300. 2884800. 07103024

08 2.39415 586300. 2885700. 08090924

09 2.28797 586600. 2885400. 09042624

10 2.08364 586600. 2885300. 10062424

HIGH 8-Hour

 06 4.54141 586700. 2885300. 06100316

07 4.74268 586100. 2884700. 07103024

08 4.91259 586500. 2885700. 08090916

09 5.18362 586700. 2885400. 09042616

10 4.84858 586700. 2885500. 10051216

HIGH 3-Hour

 06 5.13537 586700. 2885300. 06100312

07 5.14473 586200. 2884700. 07103021
 08 5.30990 586700. 2885500. 08083015

09 5.66290 586700. 2885600. 09081612

10 5.56747 586700. 2885600. 10072012

HIGH 1-Hour

 06 5.75761 586200. 2884800. 06110404

07 5.82159 586200. 2884700. 07103019

08 5.82275 588100. 2885600. 08051212

09 5.80008 586800. 2885500. 09081611

 10 5.65430 586700. 2885600. 10072012

SOURCE GROUP ID: O7535

Annual

 06 0.22617 586800.0 2885800.0 06123124

07 0.23042 586600.0 2885400.0 07123124

08 0.26618 586800.0 2885900.0 08123124

09 0.33769 586900.0 2885900.0 09123124

10 0.22985 586800.0 2886000.0 10123124

HIGH 24-Hour

 06 1.93928 586500. 2885000. 06110424

07 2.66998 586300. 2884800. 07103024

08 2.14815 586400. 2885700. 08090924

09 2.15197 586600. 2885400. 09042624

10 1.92664 586600. 2885300. 10062424

HIGH 8-Hour

 06 4.20491 586600. 2885300. 06100316

07 4.30235 586600. 2885300. 07032616

08 4.55844 586600. 2885800. 08083116

09 4.87133 586600. 2885400. 09042616

10 4.46700 586700. 2885500. 10051216

HIGH 3-Hour

 06 4.74783 586700. 2885300. 06100312

07 4.79170 586600. 2885300. 07100615

08 5.02290 586600. 2885800. 08083115

09 5.28175 586700. 2885600. 09081612

10 5.18143 586700. 2885600. 10072012

HIGH 1-Hour

 06 5.32407 586700. 2885400. 06082912

07 5.20176 586700. 2885400. 07052711

08 5.40388 588100. 2885600. 08051212

09 5.47831 588200. 2885700. 09030114

10 5.30621 586700. 2885600. 10072012

SOURCE GROUP ID: O5095

Annual

 06 0.30331 586800.0 2885800.0 06123124

07 0.30728 586700.0 2885400.0 07123124

08 0.34637 586800.0 2885900.0 08123124

09 0.42703 586900.0 2885900.0 09123124

10 0.30571 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 2.79975 586500. 2885000. 06110424

07 3.80206 586500. 2884900. 07103024

08 3.12445 586300. 2885700. 08090924

09 2.71128 586700. 2885400. 09042624

10 2.46868 586600. 2885300. 10062424

HIGH 8-Hour
 06 5.64548 586700. 2885100. 06110416

07 6.19603 586300. 2884800. 07103024

08 5.94213 586700. 2885100. 08101416

09 6.18741 586700. 2885400. 09042616

10 5.79805 586700. 2885500. 10051216

HIGH 3-Hour

 06 6.23965 586700. 2885300. 06100312

07 6.62539 586300. 2884800. 07103021

08 6.33455 586700. 2885400. 08031715

09 6.60498 586700. 2885600. 09081612

10 6.75053 586700. 2885600. 10072012

HIGH 1-Hour

 06 7.22887 586300. 2884900. 06110404

07 7.26600 586300. 2884800. 07103019

08 7.01065 588100. 2885600. 08051212

09 7.01484 588000. 2885800. 09030113

10 6.77404 586700. 2885600. 10072011

SOURCE GROUP ID: O5075

Annual

 06 0.29005 586800.0 2885800.0 06123124

07 0.29317 586700.0 2885400.0 07123124

08 0.33279 586800.0 2885900.0 08123124

09 0.41216 586900.0 2885900.0 09123124

10 0.29259 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 2.68500 586500. 2885000. 06110424

07 3.59912 586500. 2884900. 07103024

08 2.94505 586300. 2885700. 08090924

09 2.60502 586600. 2885400. 09042624

10 2.37247 586600. 2885300. 10062424

HIGH 8-Hour

 06 5.37578 586700. 2885100. 06110416

07 5.84593 586300. 2884800. 07103024

08 5.68602 586700. 2885100. 08101416

09 5.93089 586700. 2885400. 09042616

10 5.55067 586700. 2885500. 10051216

HIGH 3-Hour

 06 5.93281 586700. 2885300. 06100312

07 6.29437 586200. 2884700. 07103021

08 6.07216 586700. 2885500. 08083015

09 6.36745 586700. 2885600. 09081612

10 6.45449 586700. 2885600. 10072012

HIGH 1-Hour

 06 7.11751 586300. 2884900. 06110404

 07 6.91005 586300. 2884800. 07103019

08 6.70197 588100. 2885600. 08051212

09 6.67184 588000. 2885800. 09030113

10 6.49429 586700. 2885600. 10072012

SOURCE GROUP ID: O5035

Annual

 06 0.26640 586800.0 2885800.0 06123124

 07 0.26936 586600.0 2885400.0 07123124

 08 0.30857 586800.0 2885900.0 08123124

09 0.38545 586900.0 2885900.0 09123124
 10 0.26940 586900.0 2885900.0 10123124

HIGH 24-Hour

 06 2.41418 586500. 2885000. 06110424

07 3.27768 586300. 2884800. 07103024

08 2.63792 586300. 2885700. 08090924

09 2.42393 586600. 2885400. 09042624

10 2.21236 586600. 2885300. 10062424

HIGH 8-Hour

 06 4.89554 586700. 2885100. 06110416

07 5.24419 586300. 2884800. 07103024

08 5.26537 586500. 2885700. 08090916

09 5.50750 586700. 2885400. 09042616

10 5.16699 586700. 2885500. 10051216

HIGH 3-Hour

 06 5.45095 586700. 2885300. 06100312

07 5.69174 586200. 2884700. 07103021

08 5.63173 586700. 2885500. 08083015

09 5.97416 586700. 2885600. 09081612

10 5.90002 586700. 2885600. 10072012

HIGH 1-Hour

 06 6.37588 586300. 2884900. 06110404

07 6.28154 586200. 2884700. 07103019

08 6.16357 588100. 2885600. 08051212

 09 6.18901 588200. 2885700. 09030114

 10 5.99766 586700. 2885600. 10072012

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
CO STARTING

 TITLEONE FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 9/15/11

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 24 3 1

 POLLUTID SO2

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION GA1035 POINT 587489.306 2885478.742 0.000

 LOCATION GB1035 POINT 587443.291 2885477.412 0.000

 LOCATION GC1035 POINT 587349.178 2885474.119 0.000

** LOCATION COMPRS1 POINT 587260.876 2885514.841 0.000

 LOCATION COMPRS2 POINT 587270.298 2885515.008 0.000

 LOCATION COMPRS3 POINT 587279.960 2885515.439 0.000

 LOCATION HEATER POINT 587406.240 2885460.530 0.000

** Source Parameters **

** Baseload, 35 F, GAS

 SRCPARAM GA1035 2.14 45.4 364.3 18.61 6.71

 SRCPARAM GB1035 2.14 45.4 364.3 18.61 6.71

 SRCPARAM GC1035 2.14 45.4 364.3 18.61 6.71

** MAX 2 COMPRESSORS OPERATING SIMULTANEOUSLY

** SRCPARAM COMPRS1 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS2 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS3 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM HEATER 0.0068 9.144 533.150 16.33513 0.427

** Building Downwash **

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43
SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ GA1035-GA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ GA1035-GA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ GA1035-GA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ GA1035-GA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ GA1035-GA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ GA1035-GA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ GA1035-GA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ GA1035-GA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ GA1035-GA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ GA1035-GA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ GA1035-GA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ GA1035-GA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ GB1035-GB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ GB1035-GB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ GB1035-GB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ GB1035-GB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ GB1035-GB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ GB1035-GB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ GB1035-GB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ GB1035-GB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ GB1035-GB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ GB1035-GB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ GB1035-GB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ GB1035-GB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94
SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ GC1035-GC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ GC1035-GC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ GC1035-GC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ GC1035-GC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ GC1035-GC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ GC1035-GC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ GC1035-GC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ GC1035-GC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ GC1035-GC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ GC1035-GC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ GC1035-GC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ GC1035-GC7595 14.74 12.05 8.99 5.66 2.16 -1.41

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 23.77 23.77

**SO BUILDHGT COMPRS1 23.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 33.72 33.25

**SO BUILDWID COMPRS1 31.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 23.60 27.42

**SO BUILDLEN COMPRS1 30.41 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 -117.01 -121.97

**SO XBADJ COMPRS1 -123.23 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 26.77 8.09

**SO YBADJ COMPRS1 -10.83 0.00 0.00 0.00 0.00 0.00
SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS2 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 -113.90

SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 12.95

SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS3 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00
SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 -105.75

SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 18.15

SO YBADJ COMPRS3 1.90 -14.42 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.59 33.15 33.71 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 11.96 -64.60

SO XBADJ HEATER -65.56 -64.52 -62.62 28.55 25.22 21.12

SO XBADJ HEATER 16.38 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 -41.28 38.62

SO XBADJ HEATER 43.70 47.46 -89.97 -91.62 -90.50 -48.54

SO XBADJ HEATER -46.79 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 -27.38 21.91

SO YBADJ HEATER 12.62 2.94 -6.83 2.80 9.37 15.65

SO YBADJ HEATER 21.46 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 27.38 -21.91

SO YBADJ HEATER -12.62 -2.94 2.04 -12.40 -26.47 -15.65

SO YBADJ HEATER -21.46 0.00 0.00 0.00 0.00 0.00

 SRCGROUP CTS GA1035 GB1035 GC1035

 SRCGROUP CTSHTR GA1035 GB1035 GC1035 HEATER

 SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED
**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE SECOND FOURTH

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :SO2AQS.O06

AERMOD OUTPUT FILE NUMBER 2 :SO2AQS.O07

AERMOD OUTPUT FILE NUMBER 3 :SO2AQS.O08

AERMOD OUTPUT FILE NUMBER 4 :SO2AQS.O09

AERMOD OUTPUT FILE NUMBER 5 :SO2AQS.O10

First title for last output file is: FPL FUTURE SO2 AAQS WITH MHI "J" CLASS 

GAS 9/15/11

Second title for last output file is: FT. LAUDERDALE/MIAMI FIU MET 2006-2010

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: CTS

Annual

 06 0.25487 586800.0 2885800.0 06123124

07 0.24858 586700.0 2885400.0 07123124

08 0.28153 586800.0 2885900.0 08123124

09 0.34026 586900.0 2885900.0 09123124

10 0.25512 586900.0 2885900.0 10123124

SOURCE GROUP ID: CTSHTR

Annual

 06 0.27178 586800.0 2885800.0 06123124

07 0.25967 586700.0 2885400.0 07123124

08 0.29364 586800.0 2885900.0 08123124

09 0.36007 586900.0 2885800.0 09123124

10 0.26971 586900.0 2885900.0 10123124

SOURCE GROUP ID: ALL

Annual

 06 0.30541 586900.0 2885800.0 06123124

07 0.28767 586700.0 2885400.0 07123124

08 0.32625 586900.0 2885800.0 08123124

09 0.39781 586900.0 2885800.0 09123124

10 0.29668 586900.0 2885900.0 10123124

09 0.00000 0. 0. 

 10 0.00000 0. 0. 

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
CO STARTING

 TITLEONE FPL FUTURE PM10/PM2.5 AAQS WITH MHI "J" CLASS GAS 9/15/11

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 

 POLLUTID PM10

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION OA5095 POINT 587489.306 2885478.742 0.000

 LOCATION OB5095 POINT 587443.291 2885477.412 0.000

 LOCATION OC5095 POINT 587349.178 2885474.119 0.000

** LOCATION COMPRS1 POINT 587260.876 2885514.841 0.000

 LOCATION COMPRS2 POINT 587270.298 2885515.008 0.000

 LOCATION COMPRS3 POINT 587279.960 2885515.439 0.000

 LOCATION HEATER POINT 587406.240 2885460.530 0.000

** Source Parameters **

** 50% Load, 95 F, OIL

 SRCPARAM OA5095 1.64 45.4 452.0 14.58 6.71

 SRCPARAM OB5095 1.64 45.4 452.0 14.58 6.71

 SRCPARAM OC5095 1.64 45.4 452.0 14.58 6.71

** MAX 2 COMPRESSORS OPERATING SIMULTANEOUSLY

** SRCPARAM COMPRS1 0.047 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS2 0.047 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS3 0.047 6.309 807.594 43.58640 1.067

 SRCPARAM HEATER 0.0003 9.144 533.150 16.33513 0.427

** Building Downwash **

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43
SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ OA1035-OA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ OA1035-OA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ OA1035-OA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ OA1035-OA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ OA1035-OA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ OA1035-OA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ OA1035-OA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ OA1035-OA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ OA1035-OA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ OA1035-OA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ OA1035-OA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ OA1035-OA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ OB1035-OB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ OB1035-OB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ OB1035-OB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ OB1035-OB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ OB1035-OB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ OB1035-OB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ OB1035-OB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ OB1035-OB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ OB1035-OB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ OB1035-OB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ OB1035-OB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ OB1035-OB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94
SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ OC1035-OC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ OC1035-OC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ OC1035-OC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ OC1035-OC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ OC1035-OC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ OC1035-OC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ OC1035-OC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ OC1035-OC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ OC1035-OC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ OC1035-OC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ OC1035-OC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ OC1035-OC7595 14.74 12.05 8.99 5.66 2.16 -1.41

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 23.77 23.77

**SO BUILDHGT COMPRS1 23.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 33.72 33.25

**SO BUILDWID COMPRS1 31.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 23.60 27.42

**SO BUILDLEN COMPRS1 30.41 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 -117.01 -121.97

**SO XBADJ COMPRS1 -123.23 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 26.77 8.09

**SO YBADJ COMPRS1 -10.83 0.00 0.00 0.00 0.00 0.00
SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS2 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 -113.90

SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 12.95

SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS3 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00
SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 -105.75

SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 18.15

SO YBADJ COMPRS3 1.90 -14.42 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.59 33.15 33.71 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 11.96 -64.60

SO XBADJ HEATER -65.56 -64.52 -62.62 28.55 25.22 21.12

SO XBADJ HEATER 16.38 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 -41.28 38.62

SO XBADJ HEATER 43.70 47.46 -89.97 -91.62 -90.50 -48.54

SO XBADJ HEATER -46.79 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 -27.38 21.91

SO YBADJ HEATER 12.62 2.94 -6.83 2.80 9.37 15.65

SO YBADJ HEATER 21.46 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 27.38 -21.91

SO YBADJ HEATER -12.62 -2.94 2.04 -12.40 -26.47 -15.65

SO YBADJ HEATER -21.46 0.00 0.00 0.00 0.00 0.00

SO SRCGROUP CTS OA5095 OB5095 OC5095

SO SRCGROUP CTSHTR OA5095 OB5095 OC5095 HEATER

SO SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou
RE FINISHED

**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :PM10AQS.O06

AERMOD OUTPUT FILE NUMBER 2 :PM10AQS.O07

AERMOD OUTPUT FILE NUMBER 3 :PM10AQS.O08

AERMOD OUTPUT FILE NUMBER 4 :PM10AQS.O09

AERMOD OUTPUT FILE NUMBER 5 :PM10AQS.O10

First title for last output file is: FPL FUTURE PM10/PM2.5 AAQS WITH MHI "J" 

CLASS GAS 9/15/11

Second title for last output file is: FT. LAUDERDALE/MIAMI FIU MET 2006-2010

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: CTS

Annual

 06 0.14923 586800.0 2885800.0 06123124

 07 0.15118 586700.0 2885400.0 07123124

08 0.17042 586800.0 2885900.0 08123124

09 0.21010 586900.0 2885900.0 09123124

10 0.15041 586900.0 2885900.0 10123124

SOURCE GROUP ID: CTSHTR

Annual

 06 0.14998 586800.0 2885800.0 06123124

07 0.15167 586700.0 2885400.0 07123124

08 0.17095 586800.0 2885900.0 08123124

09 0.21073 586900.0 2885900.0 09123124

10 0.15105 586900.0 2885900.0 10123124

SOURCE GROUP ID: ALL

Annual

 06 0.18859 586900.0 2885800.0 06123124

07 0.18424 586700.0 2885400.0 07123124

08 0.20685 586900.0 2885800.0 08123124

09 0.25394 586900.0 2885800.0 09123124

10 0.18350 586900.0 2885800.0 10123124

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
CO STARTING

 TITLEONE FPL FUTURE NO2 AAQS WITH MHI "J" CLASS GAS 9/15/11

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME PERIOD

 POLLUTID NO2

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION OA1035 POINT 587489.306 2885478.742 0.000

 LOCATION OB1035 POINT 587443.291 2885477.412 0.000

 LOCATION OC1035 POINT 587349.178 2885474.119 0.000

** LOCATION COMPRS1 POINT 587260.876 2885514.841 0.000

 LOCATION COMPRS2 POINT 587270.298 2885515.008 0.000

 LOCATION COMPRS3 POINT 587279.960 2885515.439 0.000

 LOCATION HEATER POINT 587406.240 2885460.530 0.000

** Source Parameters **

** Baseload, 35 F, OIL

 SRCPARAM OA1035 9.85 45.4 454.8 23.51 6.71

 SRCPARAM OB1035 9.85 45.4 454.8 23.51 6.71

 SRCPARAM OC1035 9.85 45.4 454.8 23.51 6.71

** MAX 2 COMPRESSORS OPERATING SIMULTANEOUSLY AT WORST CASE EMISSIONS

** SRCPARAM COMPRS1 0.399 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS2 0.399 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS3 0.399 6.309 807.594 43.58640 1.067

 SRCPARAM HEATER 0.12 9.144 533.150 16.33513 0.427

** Building Downwash **

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43
SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ OA1035-OA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ OA1035-OA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ OA1035-OA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ OA1035-OA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ OA1035-OA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ OA1035-OA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ OA1035-OA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ OA1035-OA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ OA1035-OA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ OA1035-OA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ OA1035-OA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ OA1035-OA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ OB1035-OB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ OB1035-OB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ OB1035-OB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ OB1035-OB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ OB1035-OB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ OB1035-OB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ OB1035-OB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ OB1035-OB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ OB1035-OB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ OB1035-OB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ OB1035-OB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ OB1035-OB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94
SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ OC1035-OC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ OC1035-OC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ OC1035-OC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ OC1035-OC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ OC1035-OC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ OC1035-OC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ OC1035-OC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ OC1035-OC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ OC1035-OC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ OC1035-OC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ OC1035-OC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ OC1035-OC7595 14.74 12.05 8.99 5.66 2.16 -1.41

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 23.77 23.77

**SO BUILDHGT COMPRS1 23.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 33.72 33.25

**SO BUILDWID COMPRS1 31.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 23.60 27.42

**SO BUILDLEN COMPRS1 30.41 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 -117.01 -121.97

**SO XBADJ COMPRS1 -123.23 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 26.77 8.09

**SO YBADJ COMPRS1 -10.83 0.00 0.00 0.00 0.00 0.00
SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS2 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 -113.90

SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 12.95

SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS3 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00
SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 -105.75

SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 18.15

SO YBADJ COMPRS3 1.90 -14.42 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.59 33.15 33.71 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 11.96 -64.60

SO XBADJ HEATER -65.56 -64.52 -62.62 28.55 25.22 21.12

SO XBADJ HEATER 16.38 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 -41.28 38.62

SO XBADJ HEATER 43.70 47.46 -89.97 -91.62 -90.50 -48.54

SO XBADJ HEATER -46.79 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 -27.38 21.91

SO YBADJ HEATER 12.62 2.94 -6.83 2.80 9.37 15.65

SO YBADJ HEATER 21.46 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 27.38 -21.91

SO YBADJ HEATER -12.62 -2.94 2.04 -12.40 -26.47 -15.65

SO YBADJ HEATER -21.46 0.00 0.00 0.00 0.00 0.00

SO SRCGROUP CTS OA1035 OB1035 OC1035

SO SRCGROUP CTSHTR OA1035 OB1035 OC1035 HEATER

SO SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED
**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :NO2AQS.O06

AERMOD OUTPUT FILE NUMBER 2 :NO2AQS.O07

AERMOD OUTPUT FILE NUMBER 3 :NO2AQS.O08

AERMOD OUTPUT FILE NUMBER 4 :NO2AQS.O09

AERMOD OUTPUT FILE NUMBER 5 :NO2AQS.O10

First title for last output file is: FPL FUTURE NO2 AAQS WITH MHI "J" CLASS 

GAS 9/15/11

Second title for last output file is: FT. LAUDERDALE/MIAMI FIU MET 2006-2010

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: CTS

Annual

 06 0.53718 586700.0 2885800.0 06123124

07 0.55017 586600.0 2885400.0 07123124

08 0.64321 586800.0 2885900.0 08123124

09 0.83588 586800.0 2885900.0 09123124

10 0.55017 586800.0 2886000.0 10123124

SOURCE GROUP ID: CTSHTR

Annual

 06 1.23887 587199.3 2885584.5 06123124

07 1.28448 587204.6 2885442.2 07123124

08 1.25682 587202.9 2885489.8 08123124

09 1.43689 587199.3 2885584.5 09123124

10 1.20622 587199.3 2885584.5 10123124

SOURCE GROUP ID: ALL

Annual

 06 1.50733 587199.3 2885584.5 06123124

07 1.39892 587199.3 2885584.5 07123124

08 1.45308 587000.0 2885700.0 08123124

09 1.83210 587000.0 2885700.0 09123124

10 1.48789 587199.3 2885584.5 10123124

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
CO STARTING

 TITLEONE FPL FUTURE CO AAQS WITH MHI "J" CLASS GAS 9/16/11

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME 8 1

 POLLUTID CO

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION OA1035 POINT 587489.306 2885478.742 0.000

 LOCATION OB1035 POINT 587443.291 2885477.412 0.000

 LOCATION OC1035 POINT 587349.178 2885474.119 0.000

** LOCATION COMPRS1 POINT 587260.876 2885514.841 0.000

 LOCATION COMPRS2 POINT 587270.298 2885515.008 0.000

 LOCATION COMPRS3 POINT 587279.960 2885515.439 0.000

 LOCATION HEATER POINT 587406.240 2885460.530 0.000

** Source Parameters **

** Baseload, 35 F, OIL

 SRCPARAM OA1035 26.24 45.4 454.8 23.51 6.71

 SRCPARAM OB1035 26.24 45.4 454.8 23.51 6.71

 SRCPARAM OC1035 26.24 45.4 454.8 23.51 6.71

** MAX 2 COMPRESSORS OPERATING SIMULTANEOUSLY

** SRCPARAM COMPRS1 0.405 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS2 0.405 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS3 0.405 6.309 807.594 43.58640 1.067

 SRCPARAM HEATER 0.101 9.144 533.150 16.33513 0.427

** Building Downwash **

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OA1035-OA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OA1035-OA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID OA1035-OA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OA1035-OA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN OA1035-OA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN OA1035-OA7595 21.86 17.07 13.94 19.06 23.60 27.43
SO BUILDLEN OA1035-OA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ OA1035-OA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ OA1035-OA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ OA1035-OA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ OA1035-OA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ OA1035-OA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ OA1035-OA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ OA1035-OA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ OA1035-OA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ OA1035-OA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ OA1035-OA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ OA1035-OA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ OA1035-OA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OB1035-OB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID OB1035-OB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OB1035-OB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID OB1035-OB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN OB1035-OB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OB1035-OB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN OB1035-OB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ OB1035-OB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ OB1035-OB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ OB1035-OB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ OB1035-OB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ OB1035-OB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ OB1035-OB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ OB1035-OB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ OB1035-OB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ OB1035-OB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ OB1035-OB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ OB1035-OB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ OB1035-OB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT OC1035-OC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94
SO BUILDWID OC1035-OC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID OC1035-OC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID OC1035-OC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN OC1035-OC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN OC1035-OC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN OC1035-OC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ OC1035-OC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ OC1035-OC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ OC1035-OC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ OC1035-OC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ OC1035-OC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ OC1035-OC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ OC1035-OC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ OC1035-OC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ OC1035-OC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ OC1035-OC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ OC1035-OC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ OC1035-OC7595 14.74 12.05 8.99 5.66 2.16 -1.41

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 23.77 23.77

**SO BUILDHGT COMPRS1 23.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 33.72 33.25

**SO BUILDWID COMPRS1 31.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 23.60 27.42

**SO BUILDLEN COMPRS1 30.41 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 -117.01 -121.97

**SO XBADJ COMPRS1 -123.23 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 26.77 8.09

**SO YBADJ COMPRS1 -10.83 0.00 0.00 0.00 0.00 0.00
SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS2 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 -113.90

SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 12.95

SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS3 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00
SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 -105.75

SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 18.15

SO YBADJ COMPRS3 1.90 -14.42 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.59 33.15 33.71 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 11.96 -64.60

SO XBADJ HEATER -65.56 -64.52 -62.62 28.55 25.22 21.12

SO XBADJ HEATER 16.38 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 -41.28 38.62

SO XBADJ HEATER 43.70 47.46 -89.97 -91.62 -90.50 -48.54

SO XBADJ HEATER -46.79 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 -27.38 21.91

SO YBADJ HEATER 12.62 2.94 -6.83 2.80 9.37 15.65

SO YBADJ HEATER 21.46 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 27.38 -21.91

SO YBADJ HEATER -12.62 -2.94 2.04 -12.40 -26.47 -15.65

SO YBADJ HEATER -21.46 0.00 0.00 0.00 0.00 0.00

SO SRCGROUP CTS OA1035 OB1035 OC1035

SO SRCGROUP CTSHTR OA1035 OB1035 OC1035 HEATER

SO SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED
**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 10 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE SECOND

OU FINISHED
*** AERMOD - VERSION 11103 *** *** FPL FUTURE CO AAQS WITH MHI "J" CLASS GAS 9/16/11 *** 10/05/11

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 18:01:45

 PAGE 277

**MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF HIGHEST 8-HR RESULTS ***

 ** CONC OF CO IN MICROGRAMS/M**3 **

 DATE NETWORK

GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 30.38897 ON 09042516: AT ( 586600.00, 2885400.00, 2.14, 2.14, 0.00) DC

CTSHTR HIGH 2ND HIGH VALUE IS 30.73098 ON 09042516: AT ( 586600.00, 2885400.00, 2.14, 2.14, 0.00) DC

ALL HIGH 2ND HIGH VALUE IS 32.16527 ON 09042516: AT ( 586600.00, 2885500.00, 2.90, 2.90, 0.00) DC

*** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

DC = DISCCART

DP = DISCPOLR
*** AERMOD - VERSION 11103 *** *** FPL FUTURE CO AAQS WITH MHI "J" CLASS GAS 9/16/11 *** 10/05/11

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 18:01:45

 PAGE 278

**MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF HIGHEST 1-HR RESULTS ***

 ** CONC OF CO IN MICROGRAMS/M**3 **

 DATE NETWORK

GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 35.60065 ON 09051613: AT ( 586600.00, 2885600.00, 3.00, 3.00, 0.00) DC

CTSHTR HIGH 2ND HIGH VALUE IS 36.15898 ON 09042613: AT ( 586700.00, 2885400.00, 2.00, 2.00, 0.00) DC

ALL HIGH 2ND HIGH VALUE IS 38.26358 ON 09042613: AT ( 586700.00, 2885400.00, 2.00, 2.00, 0.00) DC

*** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

DC = DISCCART

DP = DISCPOLR
*** AERMOD - VERSION 11103 *** *** FPL FUTURE CO AAQS WITH MHI "J" CLASS GAS 9/16/11 *** 10/05/11

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 18:01:45

 PAGE 279

**MODELOPTs: RegDFAULT CONC ELEV

*** Message Summary : AERMOD Model Execution ***

 --------- Summary of Total Messages --------

A Total of 0 Fatal Error Message(s)

A Total of 3 Warning Message(s)

A Total of 2306 Informational Message(s)

A Total of 43824 Hours Were Processed

A Total of 1269 Calm Hours Identified

A Total of 1037 Missing Hours Identified ( 2.37 Percent)

 ******** FATAL ERROR MESSAGES ********

 *** NONE ***

 ******** WARNING MESSAGES ********

CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: OA1035

CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: OB1035

CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: OC1035

 ************************************

 *** AERMOD Finishes Successfully ***

 ************************************
CO STARTING

 TITLEONE FPL FUTURE AUX BOILER 2006 11/6/11

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 24 8 3 1 

 POLLUTID GEN

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION AUXBLR POINT 587484.850 2885500.690 0.000

** Source Parameters **

 SRCPARAM AUXBLR 10.0 18.288 419.817 25.08504 0.838 

** Building Downwash **

SO BUILDHGT AUXBLR 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT AUXBLR 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT AUXBLR 0.00 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT AUXBLR 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT AUXBLR 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT AUXBLR 0.00 23.77 23.77 23.77 23.77 23.77

SO BUILDWID AUXBLR 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID AUXBLR 33.62 0.00 0.00 0.00 0.00 0.00

SO BUILDWID AUXBLR 0.00 29.31 25.98 21.86 17.07 13.94

SO BUILDWID AUXBLR 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID AUXBLR 33.62 0.00 0.00 0.00 0.00 0.00

SO BUILDWID AUXBLR 0.00 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN AUXBLR 33.15 33.71 33.25 31.77 29.32 25.98

SO BUILDLEN AUXBLR 21.86 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN AUXBLR 0.00 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN AUXBLR 33.15 33.71 33.25 31.77 29.32 25.98

SO BUILDLEN AUXBLR 21.86 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN AUXBLR 0.00 32.49 33.57 33.63 32.66 31.59

SO XBADJ AUXBLR -57.38 -55.01 -75.06 -75.71 -74.07 -70.18

SO XBADJ AUXBLR -64.16 0.00 0.00 0.00 0.00 0.00

SO XBADJ AUXBLR 0.00 18.91 21.96 24.35 25.99 26.41

SO XBADJ AUXBLR 24.23 21.30 41.81 43.95 44.75 44.20

SO XBADJ AUXBLR 42.30 0.00 0.00 0.00 0.00 0.00

SO XBADJ AUXBLR 0.00 -51.40 -55.53 -57.97 -58.66 -58.00

SO YBADJ AUXBLR -11.65 -18.56 13.17 2.82 -7.61 -17.81

SO YBADJ AUXBLR -27.47 0.00 0.00 0.00 0.00 0.00

SO YBADJ AUXBLR 0.00 -23.77 -17.30 -10.31 -3.01 4.39

SO YBADJ AUXBLR 11.65 18.56 -13.17 -2.82 7.61 17.81

SO YBADJ AUXBLR 27.47 0.00 0.00 0.00 0.00 0.00

SO YBADJ AUXBLR 0.00 23.77 17.30 10.31 3.01 -4.39
SO SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED

**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 06 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE FIRST

OU FINISHED
 AERBOB RELEASE 110422

AERMOD OUTPUT FILE NUMBER 1 :AUXBLR.O06 

AERMOD OUTPUT FILE NUMBER 2 :AUXBLR.O07 

AERMOD OUTPUT FILE NUMBER 3 :AUXBLR.O08 

AERMOD OUTPUT FILE NUMBER 4 :AUXBLR.O09 

AERMOD OUTPUT FILE NUMBER 5 :AUXBLR.O10 

First title for last output file is: FPL FUTURE AUX BOILER 2006 11/6/11 

Second title for last output file is: FT. LAUDERDALE/MIAMI FIU MET 2006-2010 

 

 

AVERAGING TIME YEAR CONC X Y PERIOD ENDING

 (ug/m3) (m) (m) (YYMMDDHH)

------------------------------------------------------------------------------

SOURCE GROUP ID: ALL 

Annual

 06 17.66699 587208.3 2885347.8 06123124

07 20.43161 587208.3 2885347.8 07123124

08 19.19727 587208.3 2885347.8 08123124

09 12.09807 587206.4 2885395.0 09123124

10 15.35933 587208.3 2885347.8 10123124

HIGH 24-Hour

 06 197.20378 587208. 2885348. 06121924

07 171.73849 587208. 2885348. 07101324

08 170.51404 587208. 2885348. 08101524

09 160.74315 587208. 2885348. 09020824

10 163.52295 587208. 2885348. 10052224

HIGH 8-Hour

 06 239.00926 587212. 2885253. 06050224

07 270.38324 587688. 2885128. 07110508

08 266.61246 587641. 2885127. 08120808

09 274.74942 587735. 2885130. 09123008

10 286.11209 587208. 2885348. 10052208

HIGH 3-Hour

 06 352.17694 587830. 2885134. 06020524

07 393.86838 587641. 2885127. 07083003

08 367.52280 587688. 2885128. 08112503

09 358.88657 587688. 2885128. 09011003

10 392.66406 587641. 2885127. 10121603

HIGH 1-Hour

 06 538.81488 587264. 2885112. 06100623

07 555.29004 587215. 2885158. 07091220

08 540.68488 587215. 2885158. 08120422

09 535.49683 587212. 2885253. 09091903

 10 542.40936 587100. 2885200. 10061822

 All receptor computations reported with respect to a user-specified origin

GRID 0.00 0.00

DISCRETE 0.00 0.00
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.IN

Page: 1 1/18/2012

CO STARTING

 TITLEONE FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12

 TITLETWO FT. LAUDERDALE/MIAMI FIU MET 2006-2010

 MODELOPT DFAULT CONC

 AVERTIME PERIOD 24 3 1

 POLLUTID SO2

 RUNORNOT RUN

CO FINISHED

**

****************************************

** ISCST3 Source Pathway

****************************************

**

**

SO STARTING

** Source Location **

** Source ID - Type - X Coord. - Y Coord. **

 LOCATION GA1035 POINT 587489.306 2885478.742 0.000

 LOCATION GB1035 POINT 587443.291 2885477.412 0.000

 LOCATION GC1035 POINT 587349.178 2885474.119 0.000

** LOCATION COMPRS1 POINT 587260.876 2885514.841 0.000

 LOCATION COMPRS2 POINT 587270.298 2885515.008 0.000

 LOCATION COMPRS3 POINT 587279.960 2885515.439 0.000

 LOCATION HEATER POINT 587406.240 2885460.530 0.000

** Source Parameters **

** Baseload, 35 F, GAS

 SRCPARAM GA1035 2.14 45.4 364.3 18.61 6.71

 SRCPARAM GB1035 2.14 45.4 364.3 18.61 6.71

 SRCPARAM GC1035 2.14 45.4 364.3 18.61 6.71

** MAX 2 COMPRESSORS OPERATING SIMULTANEOUSLY

** SRCPARAM COMPRS1 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS2 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM COMPRS3 0.0404 6.309 807.594 43.58640 1.067

 SRCPARAM HEATER 0.0068 9.144 533.150 16.33513 0.427

** Building Downwash **

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GA1035-GA7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GA1035-GA7595 19.06 23.60 27.43 30.41 32.48 33.56

SO BUILDWID GA1035-GA7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GA1035-GA7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO BUILDLEN GA1035-GA7595 33.15 33.71 33.24 31.77 29.32 25.98

SO BUILDLEN GA1035-GA7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GA1035-GA7595 30.42 32.49 33.57 33.63 32.66 31.59

SO XBADJ GA1035-GA7595 -36.54 -35.91 -34.20 -61.77 -63.38 -63.07

SO XBADJ GA1035-GA7595 -60.84 -56.76 -7.04 -6.08 -4.94 -3.65

SO XBADJ GA1035-GA7595 -2.24 -0.77 0.72 2.20 3.60 4.46

SO XBADJ GA1035-GA7595 3.38 2.20 0.96 30.00 34.06 37.08

SO XBADJ GA1035-GA7595 38.98 39.69 -6.90 -12.98 -18.66 -23.78

SO XBADJ GA1035-GA7595 -28.18 -31.71 -34.29 -35.82 -36.27 -36.05

SO YBADJ GA1035-GA7595 -3.45 -6.86 -10.07 20.35 12.07 3.43

SO YBADJ GA1035-GA7595 -5.32 -13.91 -20.25 -19.96 -19.06 -17.58

SO YBADJ GA1035-GA7595 -15.56 -13.07 -10.19 -6.99 -3.59 -0.07

SO YBADJ GA1035-GA7595 3.45 6.86 10.07 -20.35 -12.07 -3.43

SO YBADJ GA1035-GA7595 5.32 13.91 20.26 19.96 19.06 17.58

SO YBADJ GA1035-GA7595 15.56 13.07 10.19 6.99 3.59 0.07

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GB1035-GB7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.IN

Page: 2 1/18/2012

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDWID GB1035-GB7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GB1035-GB7595 33.62 32.65 31.59 33.15 33.71 33.24

SO BUILDWID GB1035-GB7595 31.76 29.31 25.98 21.86 17.07 13.94

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO BUILDLEN GB1035-GB7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GB1035-GB7595 21.86 17.07 13.94 19.06 23.60 27.43

SO BUILDLEN GB1035-GB7595 30.42 32.49 33.56 33.62 32.65 31.60

SO XBADJ GB1035-GB7595 -36.84 -36.03 -34.11 -31.17 -27.27 -105.13

SO XBADJ GB1035-GB7595 -106.15 -103.94 38.98 39.01 37.85 35.54

SO XBADJ GB1035-GB7595 32.16 27.79 1.65 3.00 4.26 4.94

SO XBADJ GB1035-GB7595 3.68 2.31 0.87 -0.60 -2.05 -3.44

SO XBADJ GB1035-GB7595 -4.72 -5.86 -52.92 -58.07 -61.45 -62.97

SO XBADJ GB1035-GB7595 -62.57 -60.28 -35.21 -36.62 -36.92 -36.54

SO YBADJ GB1035-GB7595 -4.53 -7.98 -11.18 -14.05 -16.49 25.82

SO YBADJ GB1035-GB7595 9.43 -7.25 -18.92 -10.66 -2.07 6.59

SO YBADJ GB1035-GB7595 15.04 23.03 -9.56 -6.21 -2.68 0.94

SO YBADJ GB1035-GB7595 4.53 7.98 11.18 14.05 16.49 18.43

SO YBADJ GB1035-GB7595 19.81 20.59 18.92 10.66 2.07 -6.59

SO YBADJ GB1035-GB7595 -15.04 -23.04 9.56 6.21 2.68 -0.94

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT GC1035-GC7595 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDWID GC1035-GC7595 19.06 23.60 27.42 30.41 32.48 33.56

SO BUILDWID GC1035-GC7595 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID GC1035-GC7595 31.77 29.32 25.98 21.86 17.07 13.94

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO BUILDLEN GC1035-GC7595 33.16 33.72 33.25 31.77 29.32 25.98

SO BUILDLEN GC1035-GC7595 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN GC1035-GC7595 30.41 32.48 33.56 33.62 32.65 31.60

SO XBADJ GC1035-GC7595 -36.45 -35.56 -33.60 -30.62 -26.71 -21.98

SO XBADJ GC1035-GC7595 -16.59 -10.69 -5.56 -4.60 -3.49 -2.28

SO XBADJ GC1035-GC7595 -1.00 0.31 1.61 2.86 4.03 4.62

SO XBADJ GC1035-GC7595 3.28 1.85 0.36 -1.15 -2.61 -4.00

SO XBADJ GC1035-GC7595 -5.27 -6.38 -8.38 -14.46 -107.09 -25.14

SO XBADJ GC1035-GC7595 -29.41 -32.79 -35.17 -36.48 -36.68 -36.22

SO YBADJ GC1035-GC7595 -4.93 -8.31 -11.43 -14.21 -16.55 -18.39

SO YBADJ GC1035-GC7595 -19.67 -20.35 -20.42 -19.86 -18.71 -16.98

SO YBADJ GC1035-GC7595 -14.74 -12.05 -8.99 -5.66 -2.16 1.41

SO YBADJ GC1035-GC7595 4.93 8.31 11.43 14.21 16.55 18.39

SO YBADJ GC1035-GC7595 19.67 20.35 20.42 19.86 -16.11 16.98

SO YBADJ GC1035-GC7595 14.74 12.05 8.99 5.66 2.16 -1.41

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDHGT COMPRS1 0.00 0.00 0.00 0.00 23.77 23.77

**SO BUILDHGT COMPRS1 23.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDWID COMPRS1 0.00 0.00 0.00 0.00 33.72 33.25

**SO BUILDWID COMPRS1 31.77 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO BUILDLEN COMPRS1 0.00 0.00 0.00 0.00 23.60 27.42

**SO BUILDLEN COMPRS1 30.41 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.IN

Page: 3 1/18/2012

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO XBADJ COMPRS1 0.00 0.00 0.00 0.00 -117.01 -121.97

**SO XBADJ COMPRS1 -123.23 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 0.00 0.00

**SO YBADJ COMPRS1 0.00 0.00 0.00 0.00 26.77 8.09

**SO YBADJ COMPRS1 -10.83 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS2 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS2 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 -113.90

SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS2 0.00 0.00 0.00 0.00 0.00 12.95

SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.00 0.00 23.77

SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDWID COMPRS3 0.00 0.00 0.00 0.00 0.00 33.25

SO BUILDWID COMPRS3 31.77 29.32 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.00 0.00 27.42

SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO XBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 -105.75

SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 0.00

SO YBADJ COMPRS3 0.00 0.00 0.00 0.00 0.00 18.15

SO YBADJ COMPRS3 1.90 -14.42 0.00 0.00 0.00 0.00
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.IN

Page: 4 1/18/2012

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDHGT HEATER 0.00 0.00 0.00 0.00 23.77 23.77

SO BUILDHGT HEATER 23.77 23.77 23.77 23.77 23.77 23.77

SO BUILDHGT HEATER 23.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.60 33.16 33.72 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDWID HEATER 0.00 0.00 0.00 0.00 32.48 33.56

SO BUILDWID HEATER 33.62 32.65 31.59 33.15 33.71 33.25

SO BUILDWID HEATER 31.77 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO BUILDLEN HEATER 0.00 0.00 0.00 0.00 29.32 25.98

SO BUILDLEN HEATER 21.86 17.07 13.94 19.06 23.60 27.42

SO BUILDLEN HEATER 30.41 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 11.96 -64.60

SO XBADJ HEATER -65.56 -64.52 -62.62 28.55 25.22 21.12

SO XBADJ HEATER 16.38 0.00 0.00 0.00 0.00 0.00

SO XBADJ HEATER 0.00 0.00 0.00 0.00 -41.28 38.62

SO XBADJ HEATER 43.70 47.46 -89.97 -91.62 -90.50 -48.54

SO XBADJ HEATER -46.79 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 -27.38 21.91

SO YBADJ HEATER 12.62 2.94 -6.83 2.80 9.37 15.65

SO YBADJ HEATER 21.46 0.00 0.00 0.00 0.00 0.00

SO YBADJ HEATER 0.00 0.00 0.00 0.00 27.38 -21.91

SO YBADJ HEATER -12.62 -2.94 2.04 -12.40 -26.47 -15.65

SO YBADJ HEATER -21.46 0.00 0.00 0.00 0.00 0.00

 SRCGROUP CTS GA1035 GB1035 GC1035

 SRCGROUP CTSHTR GA1035 GB1035 GC1035 HEATER

 SRCGROUP ALL

SO FINISHED

**

****************************************

** ISCST3 Receptor Pathway

****************************************

**

**

RE STARTING

 INCLUDED PEM1.rou

RE FINISHED

**

****************************************

** AERMOD Meteorology Pathway

****************************************

**

**

ME STARTING

 SURFFILE s:\amodmet\FLL1M5Y.SFC

 PROFFILE s:\amodmet\FLL1M5Y.PFL

 SURFDATA 12849 2006 Fort_Lauderdale_Hollywood_Intl_AP

 UAIRDATA 92803 2006 Miami_-_FL_Intl_Univ

 PROFBASE 11 FEET

 STARTEND 06 01 01 10 12 31

ME FINISHED

**

****************************************

** AERMOD Output Pathway

****************************************

**

**

OU STARTING

 RECTABLE ALLAVE SECOND FOURTH

OU FINISHED
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.OUT

Page: 1 1/18/2012

 *** AERMOD - VERSION 11353 *** *** FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12 *** 01/12/12

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 09:07:25

 PAGE 862

 **MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF MAXIMUM PERIOD ( 43824 HRS) RESULTS ***

 ** CONC OF SO2 IN MICROGRAMS/M**3 **

 NETWORK

GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS 1ST HIGHEST VALUE IS 0.27032 AT ( 586800.00, 2885900.00, 3.00, 3.00, 0.00) DC

 2ND HIGHEST VALUE IS 0.26959 AT ( 586900.00, 2885900.00, 3.00, 3.00, 0.00) DC

 3RD HIGHEST VALUE IS 0.26459 AT ( 586900.00, 2885800.00, 2.61, 2.61, 0.00) DC

 4TH HIGHEST VALUE IS 0.26390 AT ( 586800.00, 2885800.00, 3.00, 3.00, 0.00) DC

 5TH HIGHEST VALUE IS 0.26245 AT ( 586800.00, 2886000.00, 3.00, 3.00, 0.00) DC

 6TH HIGHEST VALUE IS 0.25896 AT ( 586700.00, 2885900.00, 3.00, 3.00, 0.00) DC

 7TH HIGHEST VALUE IS 0.25594 AT ( 586700.00, 2886000.00, 3.00, 3.00, 0.00) DC

 8TH HIGHEST VALUE IS 0.25412 AT ( 586700.00, 2885800.00, 3.00, 3.00, 0.00) DC

 9TH HIGHEST VALUE IS 0.25410 AT ( 586900.00, 2886000.00, 3.00, 3.00, 0.00) DC

 10TH HIGHEST VALUE IS 0.25057 AT ( 586800.00, 2885700.00, 2.67, 2.67, 0.00) DC

CTSHTR 1ST HIGHEST VALUE IS 0.28450 AT ( 586900.00, 2885800.00, 2.61, 2.61, 0.00) DC

 2ND HIGHEST VALUE IS 0.28409 AT ( 586800.00, 2885900.00, 3.00, 3.00, 0.00) DC

 3RD HIGHEST VALUE IS 0.28334 AT ( 586900.00, 2885900.00, 3.00, 3.00, 0.00) DC

 4TH HIGHEST VALUE IS 0.28097 AT ( 586800.00, 2885800.00, 3.00, 3.00, 0.00) DC

 5TH HIGHEST VALUE IS 0.27263 AT ( 586800.00, 2886000.00, 3.00, 3.00, 0.00) DC

 6TH HIGHEST VALUE IS 0.27195 AT ( 586700.00, 2885900.00, 3.00, 3.00, 0.00) DC

 7TH HIGHEST VALUE IS 0.26832 AT ( 587000.00, 2885800.00, 2.47, 2.47, 0.00) DC

 8TH HIGHEST VALUE IS 0.26666 AT ( 586700.00, 2885800.00, 3.00, 3.00, 0.00) DC

 9TH HIGHEST VALUE IS 0.26601 AT ( 586700.00, 2886000.00, 3.00, 3.00, 0.00) DC

 10TH HIGHEST VALUE IS 0.26454 AT ( 586800.00, 2885700.00, 2.67, 2.67, 0.00) DC

ALL 1ST HIGHEST VALUE IS 0.31980 AT ( 586900.00, 2885800.00, 2.61, 2.61, 0.00) DC

 2ND HIGHEST VALUE IS 0.31152 AT ( 586800.00, 2885800.00, 3.00, 3.00, 0.00) DC

 3RD HIGHEST VALUE IS 0.31068 AT ( 586800.00, 2885900.00, 3.00, 3.00, 0.00) DC

 4TH HIGHEST VALUE IS 0.30911 AT ( 586900.00, 2885900.00, 3.00, 3.00, 0.00) DC

 5TH HIGHEST VALUE IS 0.30252 AT ( 587000.00, 2885800.00, 2.47, 2.47, 0.00) DC

 6TH HIGHEST VALUE IS 0.30132 AT ( 587000.00, 2885700.00, 1.42, 1.42, 0.00) DC

 7TH HIGHEST VALUE IS 0.29808 AT ( 586900.00, 2885700.00, 2.10, 2.10, 0.00) DC

 8TH HIGHEST VALUE IS 0.29620 AT ( 586700.00, 2885900.00, 3.00, 3.00, 0.00) DC

 9TH HIGHEST VALUE IS 0.29274 AT ( 586800.00, 2886000.00, 3.00, 3.00, 0.00) DC

 10TH HIGHEST VALUE IS 0.29004 AT ( 586700.00, 2885800.00, 3.00, 3.00, 0.00) DC

 *** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

 DC = DISCCART

 DP = DISCPOLR

 *** AERMOD - VERSION 11353 *** *** FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12 *** 01/12/12

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 09:07:25

 PAGE 863

 **MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***

 ** CONC OF SO2 IN MICROGRAMS/M**3 **

 DATE NETWORK

GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 2.41169 ON 07103124: AT ( 586200.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 1.75007 ON 10062424: AT ( 586600.00, 2885400.00, 2.14, 2.14, 0.00) DC

CTSHTR HIGH 2ND HIGH VALUE IS 2.42134 ON 07103124: AT ( 586200.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 1.78944m ON 07053024: AT ( 586700.00, 2885400.00, 2.00, 2.00, 0.00) DC

ALL HIGH 2ND HIGH VALUE IS 2.54409 ON 07103124: AT ( 586400.00, 2884900.00, 3.00, 3.00, 0.00) DC
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.OUT

Page: 2 1/18/2012

 HIGH 4TH HIGH VALUE IS 2.00884 ON 09042724: AT ( 586700.00, 2885500.00, 2.16, 2.16, 0.00) DC

 *** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

 DC = DISCCART

 DP = DISCPOLR

 *** AERMOD - VERSION 11353 *** *** FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12 *** 01/12/12

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 09:07:25

 PAGE 864

 **MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF HIGHEST 3-HR RESULTS ***

 ** CONC OF SO2 IN MICROGRAMS/M**3 **

 DATE NETWORK

GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 4.95277 ON 07103024: AT ( 586300.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 4.60408 ON 10051212: AT ( 586700.00, 2885500.00, 2.16, 2.16, 0.00) DC

CTSHTR HIGH 2ND HIGH VALUE IS 4.96428 ON 07103024: AT ( 586300.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 4.62972 ON 10051212: AT ( 586700.00, 2885500.00, 2.16, 2.16, 0.00) DC

ALL HIGH 2ND HIGH VALUE IS 5.11806 ON 07103024: AT ( 586400.00, 2884900.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 4.86659 ON 08083015: AT ( 586700.00, 2885500.00, 2.16, 2.16, 0.00) DC

 *** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

 DC = DISCCART

 DP = DISCPOLR

 *** AERMOD - VERSION 11353 *** *** FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12 *** 01/12/12

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 09:07:25

 PAGE 865

 **MODELOPTs: RegDFAULT CONC ELEV

 *** THE SUMMARY OF HIGHEST 1-HR RESULTS ***

 ** CONC OF SO2 IN MICROGRAMS/M**3 **

 DATE NETWORK

GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRID-ID

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 5.56212 ON 07103018: AT ( 586300.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 5.38008 ON 07103019: AT ( 586400.00, 2884900.00, 3.00, 3.00, 0.00) DC

CTSHTR HIGH 2ND HIGH VALUE IS 5.57363 ON 07103018: AT ( 586300.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 5.39436 ON 07103019: AT ( 586400.00, 2884900.00, 3.00, 3.00, 0.00) DC

ALL HIGH 2ND HIGH VALUE IS 5.69344 ON 07103018: AT ( 586300.00, 2884800.00, 3.00, 3.00, 0.00) DC

 HIGH 4TH HIGH VALUE IS 5.55929 ON 07103019: AT ( 586400.00, 2884900.00, 3.00, 3.00, 0.00) DC

 *** RECEPTOR TYPES: GC = GRIDCART

 GP = GRIDPOLR

 DC = DISCCART

 DP = DISCPOLR

 *** AERMOD - VERSION 11353 *** *** FPL FUTURE SO2 AAQS WITH MHI "J" CLASS GAS 1/11/12 *** 01/12/12

 *** FT. LAUDERDALE/MIAMI FIU MET 2006-2010 *** 09:07:25

 PAGE 866

 **MODELOPTs: RegDFAULT CONC ELEV

 *** Message Summary : AERMOD Model Execution ***

 --------- Summary of Total Messages --------
S:\Projects\FPL\Port Everglades Modernization Sept11\AERMOD\AAQS MHI\SO2\E-8_EXSO2.OUT

Page: 3 1/18/2012

 A Total of 0 Fatal Error Message(s)

 A Total of 6 Warning Message(s)

 A Total of 2306 Informational Message(s)

 A Total of 43824 Hours Were Processed

 A Total of 1269 Calm Hours Identified

 A Total of 1037 Missing Hours Identified ( 2.37 Percent)

 ******** FATAL ERROR MESSAGES ********

 *** NONE ***

 ******** WARNING MESSAGES ********

 CO W361 8 COCARD:Multiyear PERIOD/ANNUAL values for NO2/SO2 require MULTYEAR Opt

 CO W362 8 COCARD:Multiyear 1h NO2/SO2 processing not applicable for 24-hr Ave

 CO W362 8 COCARD:Multiyear 1h NO2/SO2 processing not applicable for 3-hr Ave

 CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: GA1035

 CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: GB1035

 CN W305 47 WAKFLG:Stack height > or = EPA formula height for SRCID: GC1035

 ************************************

 *** AERMOD Finishes Successfully ***

 ************************************