## APPENDIX 10.2.5

PREVENTION OF SIGNIFICANT DETERIORATION PERMIT APPLICATION

## APPLICATION FOR AIR CO NSTRUCTION PERMIT/ GREENHOUSE GAS PREVENTION OF SIGNIFICANT DETERIORATION PERMIT

# Department of 

# Environmental Protection
Division of Air Resource Management
APPLICATION FOR AIR PE RMIT - LONG FORM

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 1 01/2012 

### I. APPLICATION INFORMATION

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

 For any required purpose at a facility operating u nder a federally enforceable state air operation permit (FESOP) or Title V air operation permit;

 For a proposed project subject to prevention of si gnificant 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 s ource 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. S iting Number (if applicable):

### APPLICATION INFORMATION

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 2 01/2012 

### Purpose of Application
This application for air permit is be ing submitted to obtain: (Check one)

Air Construction Permit Air construction permit. Air construction permit to establish, revise, or renew a plantwide appl icability limit (PAL). Air construction permit to establish, revise, or renew a plantwide appl icability limit (PAL),

and separate air construction permit to author ize construction or m odification 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/Re newal 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 pur suant to Rule 62-213.405, F.A.C. In such case, you must also check the following box: I hereby request that the depa rtment waive the processing time

requirements of the air construc tion 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 estim ated for all other regulated pollutants are less than the PSD significant emission rates and are not subject to PSD review by FDEP.

### APPLICATION INFORMATION

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 3 01/2012 

### 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 5 01/2012 

### Application Responsible Official Certification Complete if applying for an initial, revised , or renewal Title V ai r operation permit or concurrent processing of an air construction permit and revised or renewal Title V air operation permit. If there are multiple respons ible officials, the “application responsible official” need not be the “pri mary responsible official.” 1. Application Responsible Official Name:

2. Application Responsible Offi cial 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 a ny 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 faciliti es applying for or subject to a permit under Chapter 62-213, F.A.C. For a partnership or sole proprietorship, a ge neral partner or the proprietor, respectively. For a municipality, county, state, federal, or other public agency, eith er 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 Of ficial Telephone Numbers... Telephone: ( ) ext. Fax: ( ) 5. Application Responsible Of ficial 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, base d 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 app lication 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 Florid a and rules of the Department of Environmental Protection and revisions thereof and all other ap plicable requirements identified in this application to which the Title V source is subject. I understand that a pe rmit, if granted by the department, cannot be transferred without author ization from the department, and I will promptly notify the department upon sale or legal transfer of the f acility 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 DateY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 7 01/2012 

### 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 Responsibl e Official Mailing Address... Organization/Firm: Street Address: City: State: Zip Code: 3. Facility Primary Responsibl e Official Telephone Numbers... Telephone: ( ) ext. Fax: ( 

### ) 4. Facility Primary Responsible Official E-mail Address:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 8 01/2012 

### 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, Othe r 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 EP A 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 pro posed project is subject to PSD review by EPA for Greenhouse Gas emissions only.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 9 01/2012 

### 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 NY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 10 01/2012 

### 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 11 01/2012 

### C. FACILITY ADDITIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 applica tions, except Title V air operation permit revision applications if this information w as 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 re vision applications if this information was submitted to the department within the previous fi ve 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 Co nstruction Permit Applications 1. Area Map Showing Facility Location: Attached, Document ID: See Air Report 

### Not Applicable (existing permitted facility) 

### 2. Description of Proposed Construction, Modi fication, 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 (R ule 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 12 01/2012 

### 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/ren ewal 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/rev ision/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 app lication 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 Equipmen t/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 Manageme nt 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1- 10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_FI.docx Effective: 03/11/2010 13 01/2012 

### 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 NO X 

### 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 Fo rm 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.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 14 01/2012 

### 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.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 15 01/2012 

### 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? (C heck 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 Em issions 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 addres ses, 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 addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activit ies 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.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 16 01/2012 

### 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: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 17 01/2012 

### 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 i nput when firing ultra low sulfur light oil.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 18 01/2012 

### 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 Compri sing 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.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 19 01/2012 

### 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 SC C 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.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 20 01/2012 

### 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 ELY:\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 PO LLUTANT DETAIL INFORMATION Section [ 1 

### ] Page [ 1 

### ] of [ 6 

### ] Units 1A-1C, CT/HRSGs Part iculate 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter Total - PM 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions: See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT DETAIL INFORMATION Section [ 1 

### ] Page [ 1 

### ] of [ 6 

### ] Units 1A-1C, CT/HRSGs Part iculate Matter Total - PM



### F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - ALLOWABLE EMISSIONS Complete Subsection F2 if the pollutant identi fied 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 (D escription 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 (D escription 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 (D escription 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 PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions: See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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 PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions:

See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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 PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions: See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions: See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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 PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (if required): tons/year 9.b. Projected Monitoring Period: 5 years 10 years
10. Calculation of Emissions: See Air Report, Appendix C for baseline emissi ons. 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 PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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. requir es 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/PM 10 .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 uni t is or would be s ubject 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. NO x monitoring includes diluent monitor (O 2 or CO 2 ).



### 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 ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\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 Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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 Compri sing 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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 ELY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter Total - PM 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 30 01/2012 

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### ] Page [ 5 

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### ] Auxiliary Boiler Carbon Monoxide - CO



### F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - ALLOWABLE EMISSIONS Complete Subsection F2 if the pollutant identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 31 01/2012 

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### ] 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 32 01/2012 

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### ] Page [ 6 

### ] of [ 6 

### ] Auxiliary Boiler Volatile Organic Compounds - VOC



### F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - ALLOWABLE EMISSIONS Complete Subsection F2 if the pollutant identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx 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/PM 10 .Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 34 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 2 

### ] Auxiliary Boiler



### H. CONTINUOUS MONITOR INFORMATION Complete Subsection H if this emissions uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 35 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 2 

### ] Auxiliary Boiler



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU2_AuxBlr.docx Effective: 03/11/2010 36 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 2 

### ] Auxiliary Boiler



### I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) Additional Requirements for Air Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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 Compri sing 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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 ELY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM/PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 30 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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 uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx Effective: 03/11/2010 33 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 3 

### ] Fuel Gas Heater



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\ FPL_PEEC_EU3_GasHtr.docx 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 Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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 Compri sing 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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 ELY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM/PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 30 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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. requir es 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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 uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx Effective: 03/11/2010 33 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 4 

### ] Emergency Diesel Generator



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU4_EmergGen.docx 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 Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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).Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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 Compri sing 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 Applicati on Report; operating conditions based on 75°F.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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 ELY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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 hour ly and annual emissions based on 35°F and 75°F, respectively.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription of Operating Method): Emissions presented per unit. Maximum hour ly 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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 hour ly and annual emissions based on 35°F and 75°F, respectively.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription of Operating Method): Emissions presented per unit. Maximum hour ly 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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 hour ly and annual emissions based on 35°F and 75°F, respectively.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription of Operating Method): Emissions presented per unit. Maximum hour ly 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM/PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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 hour ly and annual emissions based on 35°F and 75°F, respectively.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription of Operating Method): Emissions presented per unit. Maximum hour ly 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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 hour ly and annual emissions based on 35°F and 75°F, respectively.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 30 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription of Operating Method): Emissions presented per unit. Maximum hour ly 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx 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. requi res 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/PM 10 emissions.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 32 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 5 

### ] Compressor Station



### H. CONTINUOUS MONITOR INFORMATION Complete Subsection H if this emissions uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 33 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 5 

### ] Compressor Station



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FP L_PEEC_EU5_Compressor.docx Effective: 03/11/2010 34 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 5 

### ] Compressor Station



### I. EMISSIONS UNIT ADDITIONAL INFORMATION (CONTINUED) Additional Requirements for Air Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 fo r 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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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).Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 require ments of 40 CFR 60 Subpart IIII.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 Compri sing 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 ELY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM/PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 30 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription of Operating Method):Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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. requi res 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx Effective: 03/11/2010 33 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 6 

### ] Diesel Fire Pump Engine



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU6_FirePump.docx 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 Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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 comple ted for each regulated and unregulated emissions unit addressed in this application. Some of the s ubsections comprising the Emissions Unit Information Section of the form are optional for unregulated emi ssions units. Each such subsection is appropriately marked. Insignificant emissions units are require d 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 “unr egulated 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 perm it. 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 revi sed 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 separat e Emissions Unit Information Section (including subsections A through I as required) must be comp leted for each emissions unit addressed in this application that is subject to air construction pe rmitting 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 Secti ons submitted as part of th is application must be indicated in the space provided at the top of each page.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 15 01/2012 

### 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? (C heck 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 Em issions 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 ac tivity, which produces one or more air pollutants and which has at least one defi nable emission point (stack or vent). This Emissions Unit Information Section addr esses, 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 addr esses, as a single emissions unit, one or

more process or production units and activ ities 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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 Compri sing 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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 NSY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 21 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter Total - PM 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 22 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx Effective: 03/11/2010 23 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Particulate Matter - PM10 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 24 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx Effective: 03/11/2010 25 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Sulfur Dioxide - SO2 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 26 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx Effective: 03/11/2010 27 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Nitrogen Oxides - NOX 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 28 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 Ve ndor Certification


### 6. Allowable Emissions Comment (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx Effective: 03/11/2010 29 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Carbon Monoxide - CO 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 30 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx Effective: 03/11/2010 31 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 Subs ection E if applying for an air construction permit or concurrent proces sing of an air constr uction permit and a revised or renewal Title V operation permit. Complete for each emi ssions-limited pollutant identified in Subsection E if applyi ng for an air operation permit. Potential, Estimated Fugitive, and Ba seline & Projected Actual Emissions
1. Pollutant Emitted: Volatile Organic Compounds - VOC 

### 2. Total Percent Effici ency 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 Em issions (if required): tons/year 8.b. Baseline 24-month Period:
From: To: 9.a. Projected Actual Em issions (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.Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 32 01/2012 

### EMISSIONS UNIT INFORMATION PO LLUTANT 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 identi fied 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 (D escription 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 (D escription 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 (D escription 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_EU7_TempConstBlr.docx 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/PM 10 .Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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 uni t is or would be s ubject 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:Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx Effective: 03/11/2010 35 01/2012 

### EMISSIONS UNIT INFORMATION Section [ 7 

### ] Temporary Construction Boilers



### I. EMISSIONS UNIT ADDI TIONAL INFORMATION Additional Requirements for All App lications, 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 subm itted 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 w as 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 in formation was submitted to the department within the previous five years and would not be a ltered 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 inform ation was submitted to th e 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 comp liance 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 ApplicableY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Forms\FPL_PEEC_EU7_TempConstBlr.docx 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 Co nstruction Permit Applications 1. Control Technology Review and Analys is (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 Oper ation (Emissions Trading): Attached, Document ID: Not Applicable
Additional Requirements CommentJanuary 2012113-87618Maximum Heat Hourly Annual AnnualNo. of Input Rate/UnitFuel UsageaOperating HoursFuel UsageaHourly AnnualPollutant Units (MMBtu/hr)(106scf/hr)(hrs/yr)(106scf/hr)(lb/hr/boiler) (TPY)(103gal/hr) (103gal/hr)Natural Gas CombustionPM/PM101 150.0 0.147 1,500 220.6 7.6lb/106scf1.12 0.8SO21 150.0 0.147 1,500 220.6 2S gr/100 scfc0.84 0.6NOx1 150.0 0.147 1,500 220.6 140.0lb/106scf20.59 15.4CO 1 150.0 0.147 1,500 220.6 84lb/106scf12.35 9.3VOCd1 150.0 0.147 1,500 220.6 5.5lb/106scf0.81 0.6Ultra Low-Sulfur Diesel CombustionPM/PM101 150.0 1.110 1,500 1665.4 3.3lb/103gal3.66 2.7SO21 150.0 1.110 1,500 1665.4 157x S lb/103gale0.26 0.2NOx1 150.0 1.110 1,500 1665.4 10.0lb/103gal11.10 8.3CO 1 150.0 1.110 1,500 1665.4 5.0lb/103gal5.55 4.2VOCd1 150.0 1.110 1,500 1665.4 0.2lb/103gal0.22 0.2Footnotes:aBased on natural gas heat content of 1,020 Btu/scf and ultra low-sulfur distillate heat content of 131,500 Btu/gal, respectively.bPropane 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 combustion emission factors are based onTables 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 sulfurcontent is 0.2 gr/100scfdNon-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.Emissions FactorbATTACHMENT F1EMISSION CALCULATIONS FOR CONSTRUCTION BOILERSEmission RateAP-42Rev. 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 1 st 

### Place Gainesville, Florida 32607

January 2012

113-87618January 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 Incl uding 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 REQUIREME NTS 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 ..................................................................................... 3-11January 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 Technolog y and Applicable NSPS .......................................... 4-1

4.2.1 Nitrogen Oxides ........................................................................................... 4-2

4.2.2 Carbon Monoxide ......................................................................................... 4-3

4.2.3 Sulfur Oxides (SO 2 

### and H 2 

### SO 4 

### 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 ............................................................................................................. 6-11January 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 Da ta for the Combustion Turbines/HRSGs - Ultra Low-Sulfur Light Oil Combustion, MPS 501J CT Table 2-2B Stack, Operating, and Emission Da ta for the Combustion Turbines/HRSGs - Ultra Low-Sulfur Light Oil Combustion, Siemens H CT Table 2-3A Summary of Maximum Potential A nnual Emissions for the CTs/HRSGs, MPS 501J CTs Table 2-3B Summary of Maximum Potential A nnual 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 Da ta for the Emergency Generators
Table 2-6 Performance, Stack Parameters, and Emissions for the Natural Gas Fuel Heater

Table 2-7 Estimated Performance and Em ission Data for Fire Pump Engine Table 2-8 Performance and Emission Data for the Natural Gas Compressors Table 2-9A Summary of Maximum Potentia l Annual Emissions for PEEC, MPS 501J CTs Table 2-9B Summary of Maximum Potentia l Annual Emissions for PEEC, Siemens H CTs Table 2-10 Summary of Maximum Pote ntial 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 Everglad es 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 SO 2 

### , NO 2 

### , PM 10 

### , PM 2.5 

### , O 3 

### , and CO Concentrations Representative of PEEC Project, 2008 through 2010 Table 6-1 Summary of Predicted Pollutant Concen trations 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 Concen trations for the Existing Units 1 through 4 at Port Everglades Plant Compared to Ambient Air Quality StandardsJanuary 2012 - iv - 113-87618

TABLE OF CONTENTS

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### Table 6-5 Summary of Maximum Pollutant Con centrations 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 Concentrati ons 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 Ever glades Plant and Port Everglades Energy Center Figure 2-1 Conceptual Plot Plan Figure 2-2 Process Flow Diagram for Each CT/H RSG Train Baseload Operation, Turbine Inlet Temperature of 75°F Figure 2-3 Comparison of Historical Actual SO 2 

### , NO x 

### and PM 10 

### Annual Emissions (TPY) for the Existing Units 1 through 4 at Port Evergl ades Plant Compared to Projected Maximum Potential Annual Emissions (TPY) for PEEC Figure 2-4 Comparison of CO 2 

### 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 FilesJanuary 2012 - v - 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### LIST OF ACRONYMS °C degrees Celsius °F degrees Fahrenheit μg/m 3 

### micrograms per cubic meter AAQS Ambient Air Quality Standards AERMOD American Meteorological Society a nd 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
CH 4 

### methane
CO carbon monoxide
CO 2 

### carbon dioxide
CO 2 

### e carbon dioxide equivalent
CT combustion turbine DLE dry low emissions DLN dry low NO x 

### 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 feetJanuary 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
N 2 

### O nitrous oxide
NO 2 

### nitrogen dioxide
NO x 

### nitrogen oxides
NP National Park
NSPS New Source Performance Standards
NSR New Source Review
NWA National Wilderness Area
NWS National Weather Service
O 2 

### oxygen PFCs perfluorocarbons PM particulate matter
PM 2.5 

### particulate matter less than 2.5 microns
PM 10 

### particulate matter less than 10 micronsJanuary 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
SF 6 

### sulfur hexafluoride
SO 2 

### 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 CenterJanuary 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 generatin g 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 un its have remained in ser vice since these dates. Units 1 through 4 are authorized to operate pursu ant 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 g as. 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 approxima tely 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 Ever glades 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 Constr uction Permit Application/Greenhouse Gas (GHG) Prevention of Significant Deterioration (PSD) Appli cation consists of the re tirement 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 adva nced combustion turbines (CTs) and three heat recovery steam generators (HRSGs), which will u tilize the waste heat from the CTs to produce steam to be utilized in a single nominal 500 MW steam turb ine 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 operati on between the existing units and PEEC, which is anticipated to commence commercial operation in June 2016.January 2012 1-2 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 (CO 2 

### ) emissions from 2016 through 2047 with the Project. CO 2 

### emissions on a system wide basis will be lower with PEEC – a cumulative reduction of approximately 22 million tons of CO 2 

### 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 (SO 2 

### ) and nitrogen dioxide (NO 2 

### ), 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 perform ance 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 cooli ng using water in the form of water evaporated from a treated paper material. The evaporated wate r 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 fa cility via pipeline. No onsite storage will be provided for natural gas. Natural gas compressors w ill be installed to raise the natural gas pressure toJanuary 2012 1-3 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 Ad ministrative Code (F.A.C.) and have been approved by EPA. The Florida PSD regulations incorporate the requi rements 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 emission s 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 preconstr uction 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 regulat ed pollutant, PSD is triggered as a result of a modification at an existing facility if the differe nce 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 promulga ted regulations related to PSD and Title V GHG Tailoring Rule [75 Federal Register (FR) 31514-31608]. This change in EPA’s PSD re gulations 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 pr ojects undergoing PSD revi ew 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.January 2012 1-4 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### This Air Construction Permit Applicat ion Report is divided into six ma jor 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 majo r 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 ambien t 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).January 2012 2-1 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 2.0 PROJECT DESCRIPTION

2.1 Facility Description

The existing FPL Port Everglades Plant is located wi thin 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 comme rcial 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 14 th 

### Avenue to the east, Eisenhower Drive to the west,

and SE 26 th 

### 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-NO x 

### (DLN) combustion technology when firing natural gas and water injection when firing ULSD oil to minimize formation of nitrogen oxides (NO x 

### ). Selective catalytic reduction (SCR) will be installed in each HRSG to further reduce emissions of

NO x 

### . Natural gas will be used as the primary fuel a nd 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 th e 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)], andJanuary 2012 2-2 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

###  Approximately 18,400 Btu/lb and 129,9 00 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 cons idered 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 MM cf/hr of natural gas for each CT. Maximum potential fuel usage at 75 ° F turbine inlet temperature ranges from about 6.6 × 10 10 

### cubic feet per year (cf/yr) to 7.3 × 10 10 

### cf/yr of natural gas for PEEC.

ULSD oil use will be based on the e quivalent 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 li ght 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

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 em issions, 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) o il has lower fuel sulfur content than that assumed for natural gas (2 gr/100 scf), the maximum annual SO 2 

### 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 presente d in Figure 2-2.

During combustion, two primary types of NO x 

### are formed: fuel NO x 

### and thermal NO x 

### . Fuel NO x 

### emissions are formed through the oxidation of a portion of the nitrogen contained in the fuel.

Thermal NO x 

### emissions are generated through the oxidatio n of a portion of the nitrogen contained in

the combustion air. NO x 

### formation can be limited by loweri ng 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 NO x 

### for the CTs, equipped with SCR control systems are proposed at concentrations of 2 pa rts per million by volume dry (ppmvd) conditions, corrected to 15 percent oxygen (O 2 

### ) or less when firing natural gas and 8 ppmvd corrected to 15 percent O 2 

### or less when firing ULSD oil.

Carbon monoxide (CO) is formed by incomplete co mbustion of fuel. High combustion temperatures, adequate excess air, and good fuel/air mixing durin g 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 NO x 

### 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 O 2 

### at baseload operation and 35 ppmvd corrected to 15 percent O 2 

### with ULSD oil firing. For the Siemens “H” CTs, the expected CO emission rates when firing naturalJanuary 2012 2-4 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### gas are 5 ppmvd corrected to 15 percent O 2 

### at baseload operation, and 10 ppmvd corrected to 15 percent O 2 

### with ULSD oil firing.

Similarly, volatile organic compound (VOC) emissions are formed by incomplete combustion of fuel. High combustion temperatures, adequate excess ai r, 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 NO x 

### 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 O 2 

### at baseload operation and 10 ppmvd corrected to 15 percent O 2 

### 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 O 2 

### at baseload operation and 10 ppmvd corrected to 15 percent O 2 

### for ULSD oil firing.

SO 2 

### 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 natu ral 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 nor mally 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 in formation 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 pow er is not available. This primarily would occur during catastrophic events such as hurricanes. Ta ble 2-5 contains emissi ons and manufacturer’s information for the emergency generators proposed for PEEC. Normally these emergency generators would be operated 1 to 2 hours per mont h 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 natu ral 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 h eat natural gas above the dew point. Table 2-6 contains performance and emissions information for the fuel heater.January 2012 2-5 113-87618

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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 st ation to increase pressure from the existing Florida Gas Transmission Company, LLC (FGT) pipe line 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 an y 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 ba rrels). Appendix A provides performan ce and emissions information for the fuel oil storage tank.

2.4 Annual Emissions for PEEC Including Emissi on Reductions from the Existing Units 1 through 4

The maximum annual potential emissions for PEEC in clude air emissions from the CT/HRSGs, fuel heater, emergency generators, auxilia ry 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 comb ined 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 em issions for baseload operation and ambient temperatures of 75°F. The maximum emissions are based on 7,760 hr/yr firing natural gas andJanuary 2012 2-6 113-87618

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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 repr esents the annual average temperature.

Tables 2-9A and 2-9B compare the net emission ch anges 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 modifi cations to major sources. The historical actual emissions for the existing Port Everglades Plant th at 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 ev aluated 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 fede rally required State Implementation Plan.

As shown in these tables, there are significant emission reductions for most pollutants. For SO 2 

### , particulate matter (PM), particulate matter less than 10 microns (PM 10 

### ), and NO x 

### , 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 SO 2 

### , NO x 

### , and PM 10 

### as a result of the Project are also graphically depicted in Figures 2-3 and 2-4. Figure 2-3 pr ovides a graphical comparison of historical actual annual TPY emissions from the existing Port Evergl ades 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 SO 2 

### , NO x 

### , and PM 10 

### of 9,273 TPY (97.7% reduction), 3,878 TPY (91% reduction) and 358 TPY (59% reduction), respectively.January 2012 2-7 113-87618

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### Figure 2-4 compares the maximum potential emission rates for PEEC with historical actual GHG emission rates based on the amount of energy prod uced [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 chang es 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 evaluati on 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 emissi on 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 3 1514-31608). In EPA’s promulgation, GHGs are defined to include an aggregate group of six GHGs: CO 2 

### , methane (CH 4 

### ), nitrous oxide (N 2 

### O), hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), and sulfur hexafluoride (SF 6 

### ). Each of these GHGs has a specific Global Warming Potential that is calculated as “CO 2 

### equivalent emissions” or

CO 2 

### e that is equivalent to one ton of CO 2 

### .

For PEEC, the GHGs emitted are CO 2 

### , CH 4 

### , and N 2 

### O with one ton of CH 4 

### equivalent to 21 tons of

CO 2 

### e and one ton of N 2 

### O equivalent to 310 tons of CO 2 

### e. Tables 2-9A to 2-9B present the net emission changes resulting from the Project, reflect ing the maximum projected PEEC emissions and the resulting changes compared to the existing Un its 1 through 4, and the PSD SERs, which are thresholds for PSD review for modifications to major sources.

The CO 2 

### emission rates shown in the tables for existing Units 1 through 4 were obtained from EPA’s

Acid Rain database. Since emissions of N 2 

### O and CH 4 

### 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 CO 2 

### e rates for these pollutants. PSD review is required for GHG emissions greater than the listed PSD SER of 75,000 tons CO 2 

### e. 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.January 2012 2-8 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 star tup, the operating load of the CTs is limited by the amount of steam that can be accepted by the stea m turbine. This will resu lt 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 documente d malfunctions are allowed provided that operators employ th e best operational practices to minimize the amount and duration of emissions during such incidents. For each gas turbine/HRSG System, excess emissions of NO x 

### and CO resulting from startup, shutdown, or malfunction s hall 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 th e steam turbine, each gas turbine/HRSG system is sequentially brought on line at low load to gradually increase the temperature of the steam-el ectrical turbine and prevent th ermal 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 emissi ons 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-p ressure (HP) steam drum falls below 450 pounds per square inch gauge (psig) for at least a one-hour period.January 2012 2-9 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 ga s 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 emi ssions 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 th e gas turbine/HRSG system, excess emissions of NO x 

### 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 with in 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 achiev e 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 fo llowing permit conditions for permitted capacity and emission limits that encompass the CTs being consid ered. Please note that the Conditions are similar

in form to those authorized for the FPL Rivier a Beach Energy Center (Permit No. 0990042-006-AC).

Permitted Capacity – Combustion Turbine-Electric Ge nerators (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 equa tions) 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 pr ovided the total emissions from the PEEC ProjectJanuary 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 ppmvd a ppmvd a lb/hr b

CO d Oil

CT Normal Mode 35.0 195.3 35.0, 30 unit operating days c, d
Gas 9.0 56.7 9.0, 30 unit operating days c, d

NO x c Oil 8.0 84.6 8.0, 30 unit operating days c, d
Gas 2.0 20.5 2.0, 30 unit operating days c, d

VOC f Oil 10.0 37.0 NA Gas 1.0 3.6
NH 3 g Oil/Gas CT, All Modes 5 NA NA SAM/SO 2 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- minute block average. PM/PM 10 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 evaporativ e 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 ope rating 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 a pproximately 150 MMBtu/hr, will be brought onsite for use only during the construction of PEEC. The boilers will provide steam for HRSG cleaning andJanuary 2012 2-11 113-87618

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### associated steam blows. Each boiler will be fired w ith 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 emissi ons 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 aux iliary boiler is constructe d and available for use during the construction period where steam is require d, one or both temporary boilers may not be

needed.January 2012 3-1 113-87618

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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 lo cal 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 pr otect 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 th at has the potential to emit 250 TPY or more, of any pollutant regulated under the CAA. “Potentia l 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 th e PSD SERs are also subject to PSD review.

EPA has promulgated regulations providing that certain increases above an air quality baseline

concentration level of SO 2 

### , PM 10 

### , and NO 2 

### 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 allowa ble PSD increments for SO 2 

### , PM 10 

### , and

NO 2 

### .January 2012 3-2 113-87618

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### PSD review is used to determine whether signifi cant 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 ex isting 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” th at “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 bega n on January 2, 2011, and continued through June 30, 2011. During this period GHG sources became s ubject to PSD if the increase in GHG emissions from a project exceeded 75,000 TPY of CO 2 

### e or more and the project was required to undergo PSD review for other air regulated pollutants. The second phase of the Tailoring Ru le 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 CO 2 

### e 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 op eration at a major source resulting in a net GHG
emissions increase of 75,000 TPY CO 2 

### e or more will be subject to PSD review.

For PSD purposes, GHGs are a single air pollutant de fined as the aggregate group of the following six gases: CO 2 

### , N 2 

### O, CH 4 

### , HFCs, PFCs, and SF 6 

### .January 2012 3-3 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### Once major sources become subject to PSD, these so urces 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 th at 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 pe rform a control technology review, which requires that all applicable federal and state emission limiti ng 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 whic h 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 meth odology 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 achievabl e 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.January 2012 3-4 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### (d) In no event shall application of best available control technology result in emissions of any pollutant which woul d 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 techno logies 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 s ource (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 environm ental benefits with energy, ec onomic, 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 re view, 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 baselin e and future air quality levels, and determining compliance with AAQS and allowable PSD incremen ts. 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.January 2012 3-5 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### The EPA has proposed significant impact levels fo r 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 concen tration 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 m odeling 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 app licable 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 s ource or major modification. For a new major facility or major modification, the affected pollutant s 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 th e 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 Prev ention 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 theJanuary 2012 3-6 113-87618

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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 adequa tely 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 th at exceeds GEP or any other dispersion technique. On July 8, 1985, EPA promulgated final stack hei ght 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 concentrationsJanuary 2012 3-7 113-87618

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### measured or predicted to occur when the plume inte racts with elevated terrain. Elevated terrain is defined as terrain that exceeds the height cal culated by the GEP stack height formula.

3.2.7 Additional Impact Analysis

In addition to air quality impact analyses, Florid a 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 impairme nt 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 Wildern ess 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 th e air environment. These values include visibility and those scenic, cultural, biologi cal, and recreational resources of an area that are affected by air quality. Important attributes of an area are t hose 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 co astal wetlands, dominant plant communities, unique and rare plant communities, soils and associated periphyton, and the wildlife dependent on these
communities for habitat. Rare, endemic, thr eatened, and endangered species of the NP and bioindicators of air pollution (e.g., lichens) must also be evaluated.January 2012 3-8 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 lo cated 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 Count y, 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 st andards “shall reflect the degree of emission limitation and the percentage re duction achievable through application of the best technological system of continuous emission reduction the Ad ministrator 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 Fe bruary 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

NO x 

### and SO 2 

### 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. NO x 

### emissions for these proposed CTs (i.e., >850 MMBtu/hr) are limited by Subpart KKKK to 15 ppmvd corrected to 15 percent O 2 

### and 42 ppmvd corrected to 15 percent O 2 

### for natural gas and oil firing, respectively. SO 2 

### 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 requi rements for performance te sting and monitoring in 40 CFR 60 Subpart KKKK.January 2012 3-9 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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. NO x 

### emissions for these turbines are limited by Subpart KKKK to 25 ppmvd corrected to 15 percent O 2 

### .

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 th e 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 Polluta nts (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 calculati ons is also presented in Appendices A and B.January 2012 3-10 113-87618

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### The Port Everglades Plant remain s 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 volatil e organic liquid storage vessels. Therefore, the facility is required to meet the same emissions, pe rformance 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 obta in an air permit prior to construction. Major new sources must meet the appropriate PSD and non attainment 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 contai ned 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 re view, process, and take appropriate ac tion (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.January 2012 3-11 113-87618

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### 3.5 Source Applicability

3.5.1 Area Classification

PEEC is located in Broward County, which has b een designated by EPA and FDEP as an attainment area (includes unclassifiable) for all criteria pollu tants. Broward County and surrounding counties are designated as PSD Class II areas for SO 2 

### , PM [total suspended particulate (TSP)], and NO 2 

### . The nearest Class I area to PEEC is the Everglades NP, located approximately 50 km (30 miles) from the
Site, and Chassahowitzka NWA, located mo re than 300 km (180 miles) from PEEC.

3.5.2 PSD Review

Pollutant Applicability Since the existing Units 1 through 4 will be perm anently retired, FPL will use emissions reductions

from these units to net out of PSD review for a ll PSD pollutants, except GHG, for PEEC (see Tables 2-9A and 2-9B in Section 2.0 and Table 3-3). Th e 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 thr eshold, 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 vi nyl chloride, asbestos, and beryllium are no longer evaluated in PSD review because they are addressed through the NESHAP program.

Emission Standards

NO x 

### and SO 2 

### 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.. NO x 

### emissions for these proposed CTs (i.e., >850 MMBtu/ hr) are limited by Subpart KKKK to 15 ppmvd corrected to 15 percent O 2 

### and 42 ppmvd corrected to 15 percent O 2 

### for natural gas and oil firing, respectively. SO 2 

### 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 natu ral 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 requi rements in the general provisions of 40 CFR 60January 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 NO x 

### emissions limit is 25 ppmvd corrected to 15 percent O 2 

### . For PEEC, the proposed NO x 

### emissions rate of 15 ppmvd corrected to 15 percent O 2 

### 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 N ESHAP regulations and applicability is based on whether a source is major or minor for HAPs. A f acility is classified as a major source of HAPs when the maximum potential emissions for all emission un its located at the facility exceed 10 TPY of a single HAP and 25 TPY for all HAPs. The Port Ever glades 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 th e aggregate use of oil by existing and new turbines exceeds 1,000 hours during any calendar y ear. 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 O 2 

### 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 co mpliance 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.January 2012 3-13 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### Ambient Monitoring For PEEC, the net emissions changes will be less th an 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 criteri a 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 Appr oach, 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 st ructures is included in the modeling analysis.

In addition, since the stack heights for the othe r 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 plan t 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 progra m 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 regula tions 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 (Par t 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).January 2012 3-14 113-87618

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### EPA’s Acid Rain Program applies to all exis ting 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 un its. 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 co mmences operation (e.g., first fire).

The permit would require the units to hold SO 2 

### 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 SO 2 

### emissions. Allowances can be sold, purchased, or traded.

CEM for NO x 

### is required for natural gas-fired and oil-fired affected units. SO 2 

### monitoring is also required, although use of CEM is optional. When an SO 2 

### CEM system is selected to monitor SO 2 

### mass emissions, a flow monitor is also required. Alternately, SO 2 

### 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). CO 2 

### emissions must also be determined either through a CEM (e.g., as a diluent for NO x 

### 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 gene ral, 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.January 2012 4-1 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 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 previo us 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 NO x 

### and SO 2 

### . In addition, there are also minor

emissions of PM/PM 10 

### , CO and VOCs as a result of the combus tion 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 NO x 

### , CO, SO 2 

### and sulfuric acid mist, PM/PM 10 

### , 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 o il), 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 SO 2 

### , PM/PM 10 

### , and other fuel bound

contaminants. Combustion controls will minimize the formation of NO x 

### and the formation of CO and VOCs by combustor design. Further NO x 

### reduction will be achieved by SCR. The combination of these techniques has been determin ed 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 Tu rbines 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 S ubpart KKKK emissions requirements applicable to combustion turbines greater than 30 MW apply to CT/HRSG trains associated with PEEC. The NO x 

### emissions are limited to 15 ppm corrected to 15 percent O 2 

### or 0.43 lb/MW-hr for natural gas firing and 42 ppm corrected to 15 percent O 2 

### or 1.3 lb/MW-hr for light oil firing. For PEEC, the NO x 

### emissions are limited to 2 ppm corrected to 15 percent O 2 

### and less than 0.05 lb/MW-hr when naturalJanuary 2012 4-2 113-87618

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### gas firing. For SO 2 

### 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

SO 2 

### 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 fo r 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 NO x 

### emissions limit of 25 ppmvd corrected to 15 percent O 2 

### compared to a proposed

NO x 

### emissions rate for PEEC of 15 ppmvd corrected to 15 percent O 2 

### . The EPA NSPS Subpart Dc,

Standards of Performance for Small Industrial-Commercial-Ins titutional 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 fo r Stationary Compression Ignition Internal Combustion Engines, is applicable.

4.2.1 Nitrogen Oxides

The Project will result in a net emissi ons decrease of about 3,900 TPY for NO x 

### emissions (i.e., more than 85 percent reduction from historical emissions). PSD review, including a BACT determination, is not applicable. However, the NO x 

### 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 NO x 

### emission levels of 2 ppmvd corrected to 15 percent O 2 

### when firing natural gas and 8 ppmvd corrected to 15 percent O 2 

### is consistent with recently established BACT emission limits for other combined cycle units when firing ULSD oil. Similarly, the NO x 

### emission rates proposed for the aux iliary boiler, natural gas heaters, emergency generators, and natural gas compressors have been established as BACT in previous PSD permits.

When firing natural gas, NO x 

### emissions will be controlled usin g DLN combustors. DLN combustor technology has been offered and installed by CT manufacturers to reduce NO x 

### emissions by inhibiting thermal NO x 

### formation through premixing fuel a nd 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 NO x 

### levels are achieved by introducingJanuary 2012 4-3 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### fuel primarily to the premix zones and reducing the amount of fuel being combusted from the pilot

nozzle.

NO x 

### emissions will be further controlled by SCR system s when firing either natural gas or ULSD oil. SCR is a post combustion process where NO x 

### 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 NO x 

### reduction. Flue gas NO x 

### emissions when firing natural gas will be reduced to 2 ppmvd, corrected to 15 percent O 2 

### . When firing ULSD oil, SCR will reduce NO x 

### emissions by 80 percent or more to 8 ppmvd corrected to 15 percent O 2 

### or less.

The NO x 

### emissions from the auxiliary boiler, fuel heat ers, emergency generato rs, pump fire engine, and natural gas compressors will be limited using combustion techniques. The auxiliary boiler will be equipped with low NO x 

### burners to reduce NO x 

### emissions to 0.05 lb/MMBtu (HHV). The fuel

heaters will use combustion controls to reduce NO x 

### emissions to 0.095 lb/MMBtu (HHV). The emergency generators will meet the NSPS Subpart IIII NO x 

### emission requirement s 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) technol ogy or equivalent with a maximum NO x 

### emission rate of 15 ppmvd corrected to 15 percent O 2 

### .

4.2.2 Carbon Monoxide

The Project will result in a net decrease in CO em issions 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 dete rmination, 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 bei ng considered for PEEC. The CTs will utilize advanced combustion technology with an expected CO emission rate of 9 ppmvd corrected to 15 percent O 2 

### at baseload operation when firing natural gas and 35 ppmvd corrected to 15 percent O 2 

### When firing ULSD oil. These CO emission ra tes envelope the CTs under consideration.January 2012 4-4 113-87618

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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 generato rs. The auxiliary boiler will be equipped with low

NO x 

### 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 redu ce CO emissions to 25 ppmvd corrected to 15 percent O 2 

### .

The CO emission rates proposed for the auxiliary bo iler, fuel heaters, emergency generators, and natural gas compressors have also been est ablished as BACT in previous PSD permits.

4.2.3 Sulfur Oxides (SO 2 

### and H 2 

### SO 4 

### Mist)

The Project will result in net emissions decreases of more than 9,000 TPY for SO 2 

### emissions and about 380 TPY for sulfuric acid (H 2 

### SO 4 

### ) mist (i.e., reductions of more than 95 percent for SO 2 

### and 90 percent for H 2 

### SO 4 

### from historical emissions). PSD review , including a BACT determination, is not applicable. The only feasible control for the comb ined cycle unit, auxiliary boilers, fuel heaters, emergency generators, fire pump e ngine, and natural gas compressors is combustion of clean fuels. Natural gas and ULSD oil are the cleanest fuels avai lable with maximum sulfur contents of 2 gr/100 scf for natural gas and 0.0015 percent su lfur for ULSD oil proposed for PEEC. H 2 

### SO 4 

### emissions will also be minimized by the use of low sulfur fuels. SO 2 

### 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/PM 10 

### (i.e., more than 50 percent reduction from historical emissions). PSD review, including a BACT determination, is not applicable. The use of clean fuels, char acterized by low PM and trace contaminant contents and advanced combustion techniques, results in negligible PM and PM 10 

### emissions from the combined cycle unit, auxiliary boiler, fuel heater s, emergency generators, fire pump engine, and natural gas compressors. Emission limits based on th e use of clean fuels (i.e., natural gas and ULSD oil) have been established as BACT for PM/PM 10 

### emissions in previous PSD permits.January 2012 4-5 113-87618

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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 a pplicable. 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 O 2 

### at baseload operation. When firing oil, the VOC emissions fro m the MPS “J” CTs or equivalent will be based on 10 ppmvd corrected to 15 percent O 2 

### . VOC emissions for the Siemens “H” CTs or equivalent will be based on 1 ppmvd (corrected to 15 percent O 2 

### ) when firing natural gas at baseload operation. For the Siemens “H” CTs or equivalent when firing o il, the VOC emissions will be based on 10 ppmvd corrected to 15 percent O 2 

### .

The auxiliary boiler is designed with proper co mbustion techniques to reduce VOC emissions to

0.005 lb/MMBtu. The fuel heaters will use co mbustion controls to reduce VOC emissions to 0.005 lb/MMBtu. The emergency generato rs 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 co mbustion technology to reduce VOC emissions to 12.5 ppmvd corrected to 15 percent O 2 

### .

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 em issions reductions that each available emissions reducing technology or technique w ould achieve, as well as the ener gy, environmental, economic and other costs associated with each technology or technique.January 2012 4-6 113-87618

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### EPA has recommended since 1990 that permitting aut horities use the five step “top down” BACT process to determine BACT. The top down process ca lls for all available control technologies for a given pollutant to be identified and ranked in d escending 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 ener gy, environmental, or economic impacts justify a conclusion that the top ranked tec hnology 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” pr ocess 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 promulgate d 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., NO X 

### , SO 2 

### , PM/PM 10 

### /PM 2.5 

### , 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.January 2012 4-7 113-87618

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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 pr actical application to the emissions unit and the regulated pollutant under evaluation.

EPA has placed potentially applicable control alte rnatives 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 co nsider potentially applicable control techniques from all of the above three categories.

GHGs under EPA regulations are considered as a singl e air pollutant, which is the aggregate group of the six principal gases, CO 2 

### , N 2 

### O, CH 4 

### , HFCs, PFCs, and SF 6 

### . CO 2 

### emissions result from the

oxidation of carbon in the fuel. CH 4 

### emissions result from incomplete combustion and N 2 

### O emissions result primarily from low temperature combustion. CO 2 

### , N 2 

### O, and CH 4 

### are the principal GHGs that will be emitted from the PEEC combined cycle unit.

The combustion of natural gas has the lowest emissi ons of GHGs of any fossil fuel and emits almost 30 percent less CO 2 

### than oil, and about 45 percent less CO 2 

### 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 c onsidered while recognizing at the same timeJanuary 2012 4-8 113-87618

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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 app licants and permitting authoriti es should identify all “available” GHG control options that have the potential fo r practical application to the source under

consideration. In its PSD and Title V Pe rmitting Guidance for GHGs, EPA emphasizes on two mitigation approaches for CO 2 

### – energy efficiency and carbon capture and storage (CCS).

Emissions of CH 4 

### and N 2 

### O from CTs are less than 0.5 percent of the total CO 2 

### e GHG emissions. As a result, control options for these pollutants are not practicable although an oxidation catalyst system can potentially reduce CH 4 

### emissions.

Energy Efficiency Energy efficiency falls under the general categor y 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 emis sions 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 pro cess is increased, less fuel is burned to produce the same amount of electricity. This provides the benef its of lower fuel costs and reduced air pollutant emissions (including CO 2 

### ). Several recent BACT determinations for GHG emissions concluded that high efficiency power generation technology is th e only available and feasible control technology. Efficient power production is technically feasible a nd is proposed for the PEEC combined cycle unit.

Carbon Capture and Storage Carbon capture and storage (CCS) falls under the cate gory 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 CO 2 

### emitting facilitiesJanuary 2012 4-9 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### including fossil fuel-fired power plants and industrial facilities with high purity CO 2 

### streams. As a result, EPA suggests that CCS be consider ed in Step 1 of the BACT analysis.

CCS is composed of three main components: CO 2 

### capture and/or compression, transport, and storage.

Carbon Capture – Before CO 2 

### 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 CO 2 

### diluted with nitrogen. Flue gas from natural gas combined cycle plants contains only about 4 percent CO 2 

### by volume. For effective carbon sequestration, the

CO 2 

### in the exhaust gases must be separated and c oncentrated due to the low percent by volume.

The most likely options currently identifiable for CO 2 

### 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 CO 2 

### is captured, it must be transpor ted to a carbon sequestration site. Pipelines are the most common method for transporting large quantities of CO 2 

### over long distances. Shipping CO 2 

### via pipeline involves compressing gaseous CO 2 

### to a pressure above 1,160 pounds per square inch (psi), to increase CO 2 

### density and make it easier and less expensive to transport. A CO 2 

### pipeline would be similar to a high pressure natural gas pipeline and is technically possible. CO 2 

### also can be transported as a liquid in seagoing vessels or via tankers on roads or railways. In these
instances, the CO 2 

### is held in insulated tanks at low temperatures and relatively low pressures.

Carbon Storage – In a CCS system, CO 2 

### 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 CO 2 

### is injected into the deep geologic formations through dr illed wells. Under high pressure, CO 2 

### turns to liquid and can move through a formation as a fluid. Once injected, the liquid CO 2 

### tends to be buoyant and will flow upward until it encounters a barrier of non porous rock, which can trap the CO 2 

### and prevent further upward migration. When CO 2 

### is injected into a coal seam, it is adsorbed onto the coal surfaces, and methane gas is released and produced in adj acent wells. There are other mechanisms for CO 2January 2012 4-10 113-87618

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### trapping as well: CO 2 

### 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 CO 2 

### . However, there is not much experience with saline formations as that acquired through resource r ecovery 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 op tions include liquid storage in deep ocean areas.

Oxidation Catalyst Catalytic oxidation technology, which is primarily designed to reduce CO emissions will also reduce

CH 4 

### emissions but to a lesser extent. Oxidation catalysts operate at elevated temperatures where

excess O 2 

### in the exhaust reacts with CH 4 

### to form CO 2 

### . No chemical reagent is necessary. The surface of an oxidation catalyst is typically a precious metal.

Oxidation catalysts are susceptible to fine particl es suspended in the exhaust gases that can foul and poison the catalyst. Catalyst poisoning reduces cata lyst 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 analys is, 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 technol ogy 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 isJanuary 2012 4-11 113-87618

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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 appli cable, 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 contro ls that are typically used to reduce emissions of other regulated pollutants. In a ddition, other add on c ontrols typically have an existing accessible infrastructure in place to address waste disposal and othe r offsite needs. It shou ld 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 co ntracts for offsite land acquisition (including the availability of land), the need for funding (includi ng, for example, government subsidies), timing of available transportation infrastructure, devel oping a site for secure long term storage and environmental permitting for underground GHG sequestra tion. 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 fo r 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 a nd 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 widespr ead, cost effective deployment of carbon capture and storage (CCS) within 10 years, with a goal of bri nging five to ten commercial demonstration projects online by 2016. These projects, to be deployed w ith the help of federal funding, are intended to demonstrate a range of current generation CCS t echnologies applied to coal-fired power plants and

industrial facilities. The Task Force concluded th at 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 app lication 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 CO 2 

### Geologic Sequestration (GS) Wells, as au thorized by the Safe Drinking Water Act (SDWA). The final rule establishes new fede ral requirements for the underground injection ofJanuary 2012 4-12 113-87618

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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 protec tion of undergr ound sources of drinking water (USDWs) from injection related activities. Theref ore, 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 CO 2 

### sequestration and including drilling deep holes, testing, etc., prior to approval of an in jection 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 co ncluded that CCS is not applicable to the PEEC Project, and consequently not technically feasible.

Oxidation Catalyst Catalytic oxidation is an available control technology for CH 4 

### , although no approval for its use for this purpose has occurred. The oxidation catalyst will reduce CH 4 

### with the following reaction:

CH 4 

### + 2O 2 

###  CO 2 

### + 2H 2 

### O

While CH 4 

### emissions can be reduced using an oxidation catalyst, the amount of CO 2 

### e reduced is less than 0.05 percent. Moreover, the amount of potential CO 2 

### e 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

CH 4 

### .

Step 3 – Rank Remaining Control Technologies

After the list of all available controls is narrowe d 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 cont rol effectiveness for the regulated NSR pollutantJanuary 2012 4-13 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### under review. The most effective control altern ative (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, econo mic, 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 t echnology 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 mo re 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 pro ducing electricity and fuel utilized are the most important aspects in GHG emissions from electric ge neration projects. Together, efficiency and fuel type dictate the amount of GHG emissions per unit of generation.

An important measure of the efficiency for an elec trical 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 ofJanuary 2012 4-14 113-87618

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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 ener gy 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/electri city/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 th e 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

75 o 

### F), and

 Oil firing – 6.745 to 7,171 Btu/kWh (50.6 to 47.6 percent efficiency) (Baseload at 75 o 

### 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 fossi l fueled power plants in the U.S. in 2010 and the proposed combined cycle unit is 33 percent more effi cient than all U.S. fossil fueled plants. When comparing to all type of generation using natura l gas, the proposed power block will be 20 percent more efficient than all generation using natural gas.January 2012 4-15 113-87618

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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 effici ency in the CT generated power and increased exhaust energy through the HRSG to produce more steam electric generation. Together this significantly improves the efficien cy over earlier generation combined cycle units. PEEC will have a heat rate over 10 percent lower th an average existing combined cycle plants as indicated from EIA 2009 data. The proposed Proj ect 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 translat e 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 availa ble 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 CO 2 

### on a generation basis for generation facilities located in the same subregion as the Project:

 Florida Reliability Coordination Council – 1,225.7 lb CO 2 

### /MW-hr for all generation (including nuclear), 1,417.3 lb CO 2 

### /MW-hr for total combustion, and

 FPL – 881.6 lb CO 2 

### /MW-hr for all generation (inc luding nuclear); 1,121.3 lb CO 2 

### /MW-hr for total combustion generation.

For PEEC, the net CO 2 

### emission rate on a generation b asis will range from about 740 to

760 lb CO 2 

### /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. Ther efore, the GHG emissions are much lower than the existing generation on a generati on basis and PEEC will displace le ss 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 CO 2 

### by 22 million tons from 2016 through 2047.January 2012 4-16 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### Step 5 – Select the BACT In Step 5 of the BACT determination process, the mo st effective control option not eliminated in Step 4 should be selected as BACT for the pollutant an d 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 effi ciency 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. Mo reover, the PEEC Project will be part of FPL electric generating system and as the most efficien t 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 CO 2 

### by 22 million tons from 2016 through 2047.

The CCS option was eliminated in Step 2 as not t echnically 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 CO 2 

### 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 mo re likely to be eliminated from consideration in Step 4 of the BACT analysis, even in some cases where underground storage of the captured CO 2 

### 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 CO 2 

### e/MW-hr on a 12-month rolling average that would be applicable to the Project . The BACT limit is ba sed on an annual averageJanuary 2012 4-17 113-87618

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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 ba sed on recent BACT determinations for similar combined cycle projects. First, the PacifiCorp’s Lake Side Bloc k 2 combined cycle project was issued a GHG BACTlimit of 950 lb/MW-hr by the Utah Department of Environmental Quality (Approval Order DAEAN01130310010-11; May 4, 2011). This BACT GH G limit is about 8 percent and 73 lb CO 2 

### e/MWhr higher than that proposed for PEEC. This is a difference of over 400,000 tons CO 2 

### e 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 CO 2 

### e/MW-hr higher than that proposed for

PEEC. This difference is also e quivalent to over 230,000 tons CO 2 

### e 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 CO 2 

### e/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 ge nerators, natural gas heaters, na tural gas compressor station and diesel fire pump engine are all necessary suppor t 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 lo wer 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 nece ssary 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 natu ral 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 w ill not make any meaningful reduction in total GHG emissions. Moreover, as discussed above, the PEEC project will reduce GHG emissions inJanuary 2012 4-18 113-87618

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### FPL’s system by 22 million tons from 2016 thr ough 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 give n that GHG emissions are not an individual unit issue. Rather, the GHG emissions of an entire proj ect 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 resp ect 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 pr actical 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 pollu tion control technique. The proposed auxiliary boiler, natural gas heater and natu ral 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 singl e air pollutant, which is the aggregate group of the six principal gases, CO 2 

### , N 2 

### O, CH 4 

### , HFCs, PFCs, and SF 6 

### . CO 2 

### emissions result from the

oxidation of carbon in the fuel. CH 4 

### emissions result from incomplete combustion, and N 2 

### O emissions result primarily from low temperature combustion. CO 2 

### , N 2 

### O, and CH 4 

### are the principal GHGs that will be emitted from the auxiliary boil er, emergency generators, natural gas heaters, natural gas compressor station and diesel fire pump engine. Emissions of CH 4 

### and N 2 

### O are negligible compared to CO 2 

### and specific control options for these pollutants are not practicable.

EPA recommends that permit app licants and permitting authoriti es should identify all “available” GHG control options that have the potential fo r practical application to the source underJanuary 2012 4-19 113-87618

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### consideration. In its PSD and Title V Pe rmitting Guidance for GHGs, EPA emphasizes on two mitigation approaches for CO 2 

### – energy efficiency and carbon capture and storage (CCS). CCS is not practical for CO 2 

### 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 CO 2 

### emissions potential from this equipment compared to the combined cycle system. Moreover, these units are not operated continuously or at their rated capac ities making the addition of control equipment problematic.

Energy Efficiency In the GHG BACT guidance, EPA has stressed im portance of energy efficiency for combustion sources. The auxiliary boiler will be used to pr ovide 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 th e 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 natura l gas delivered to the CT.

Similarly, the natural gas compressors are efficient natural gas turbines connected directly to natural gas compressors. These natural g as 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 fu el 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 ma ximize efficiency while meeting the required

emissions standards.

Step 2 – Identification of Technically Feasible Control Alternatives Under the second step of the top down BACT analys is, a potentially applicable control technique listed in Step 1 may be eliminated from further consideration if it is not technically feasible for theJanuary 2012 4-20 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### specific source under review. EPA considers a technol ogy to be potentially applicable if it has been demonstrated in practice or is available. The en ergy efficiency through the regulation of the amount

of fuel used is considered to be the only technically feasible CO 2 

### 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 narrowe d 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 c ontrol 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 CO 2 

### from the auxiliary boiler, emergenc y generators, natural gas heater, natural gas compressor station and diesel fire pump e ngine 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, econo mic, energy, and environmental impacts must be evaluated for each option remaining under consideration.

In the top down BACT analysis, the “top” cont rol option should be established as BACT unless the applicant demonstrates, and the permitting authorit y 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 natu ral gas compressor station will use natural gas. GHG emissions for natural gas firing is 116.9 lb CO 2 

### e/MMBtu compared to 163.6 lb CO 2 

### /MMBtu for distillate fuel oil firing based on Subpart C of 40 CFR Part 98, Mandatory Greenhouse Gas Reporting.

The emission factors include N 2 

### O and CH 4 

### 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.January 2012 4-21 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### Energy efficiency through the regul ation 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 g as heater and natural gas compressor station results in the lowest GHG emission practicable.

As mentioned in Step 1, an importa nt 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 operate d 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 ge nerators, natural gas heater, na tural 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 genera tors 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 an d only used to regulate natural gas pressure. Together, the negligible amount of GHG emissions potential, limitati on in operating hours, and use of the natural gas fuel, represents the best availa ble option in controlling GHG emissions from these

emission units. This is consistent with the defi nition 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.January 2012 5-1 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 5.0 AMBIENT MONITO RING 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 emi ssion 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 establishe d 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 Perm it Application, air quality monitoring data for other regulated pollutants are provided, which demons trate that Broward County is in attainment of the AAQS for all criteria pollutants. A summa ry of the maximum pollutant concentrations representative of air quality in Broward County fro m 2008 through 2010 is presen ted in Table 5-1. These data indicate that the maximum air quality c oncentrations measured in the region are well below applicable standards.

The monitoring data are also used to estimate ba ckground 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).January 2012 6-1 113-87618

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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 a pproximately 14,000 TPY compared to recent Plant operation, or an emission reduction of approxima tely 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 Applicat ion, 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 SO 2 

### , 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 ar e primarily due to background concentrations, particularly for the 1 hour average impacts.

For PM 10 

### , 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 SO 2 

### , the maximum total air quality impacts are primarily due to background concentrations.

For NO 2 

### and CO, the predicted maximum total air quality impacts are also primarily due to background concentrations. For PEEC alone, the predicted maximum NO 2 

### and CO impacts are about 16 and 1 percent, respectively, of the AAQS. The predicted maximum total NO 2 

### 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 ai r quality modeling methodology for the air quality impact analyses for the Project.January 2012 6-2 113-87618

Appendix 10 2 5_PEEC_PSD_Rev_0 FINAL.docx 

### 6.1 Air Modeling Analysis Approach

6.1.1 Air Modeling Scenarios

Air quality analyses were performed to assess the ma ximum 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 bac kground concentrations (see Subsection 6.1.8) to produce total air quality impacts. These impa cts were then compared to the AAQS for SO 2 

### , NO 2 

### , PM 10 

### , PM 2.5 

### , 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 we re then compared to the AAQS for SO 2 

### , NO 2 

### , PM 10 

### , PM 2.5 

### , 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 year s of meteorological data for the analysis. The

HSH concentration is calculated each year for a receptor field by:

1. Eliminating the highest concentr ation predicted at each receptor, 2. Identifying the second highest c oncentration at each receptor, and 3. Selecting the highest concen tration among these second highest concentrations.

The HSH approach is consistent with AAQS, wh ich generally allows a short term average

concentration to be exceeded on ce per year at each receptor.

For the 1-hour NO 2 

### impact, the 5-year averages of the 98 th 

### (8 th 

### highest) percentile of the daily maximum 1-hour average concentrations at each re ceptor were determined. The maximum 5-year average of these values is used to estimate the maximum impact. Similarly, for the 1-hour SO 2 

### impact, the 5-year averages of the 99 th 

### (4 th 

### 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.January 2012 6-3 113-87618

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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 ai r quality impacts for the existing Port Everglades

Plant and PEEC must be based on the models’ abilit y 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 impa cts due to the proposed sources at PEEC. AERMOD (Version 11103) is available on the EPA’s Intern et 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 cont aining the latest scientific algorithms for simulating plume behavior in all types of terrain.

AERMOD was used to predict the maximum polluta nt 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.January 2012 6-4 113-87618

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### 6.1.4 Meteorological Data

Meteorological data used in AERMOD to determin e 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 In ternational 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 w ill be retired before PEEC begins operation.

The short term emission rates were based on th e 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 SO 2 

### , 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 pres ented 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 para meters 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

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### 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 cons idered 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 ex it gas operating data for the MPS “J” CT and the Siemens “H” CT. Once the worst case operating co ndition 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 othe r 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 th e auxiliary boiler alone, which will be used to assist in startup for one of the CTs. As discus sed 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 pr ocess 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 th e 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 SO 2 

### , NO x 

### , PM 10 

### , PM 2.5 

### , and CO emissions to address the combined impact of the CTs and other PEEC sour ces. 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 GE P, building downwash effects were included in the modeling analysis (see following section on build ing downwash). In addition, since the stack heights for the other PEEC sources are also less th an 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 Pr ofile 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 na tural gas compressors were assumed to be in an
enclosed structure. However, each of the natu ral 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 include d in the air modeling analyses. With stack heights of 60 ft or less for the other PEEC sour ces, 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

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### 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 anal ysis 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 gr id was used to predict concentrations at 75 receptors spaced at 50 meter interv als. 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 we re converted to Universal Transverse Mercator (UTM) coordinates, North American Datum 83 (NAD83).

6.1.8 Background Concentrations

Background concentrations are necessary to de termine total ambient air quality impacts to demonstrate compliance with the AAQS. “Background concentrations” are defined as concentrations due to sources other than those specifically include d 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 SO 2 

### , PM 10 

### , PM 2.5 

### , NO 2 

### , and CO concentrations me asured 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 sele cted to represent background concentrations and

are as follows:

Background Concentration Pollutant Averaging Period (ppm) (μg/m 3 

### )
SO 2 

### 1-hour 0.038 99.6

3-hour 0.036 93.0 24-hour 0.008 20.9 Annual 0.0010 2.6

PM 10 

### 24-hour NA 18.1 Annual NA 49

PM 2.5 

### 24-hour NA 7.1 Annual NA 16

NO 2 

### 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 determ ine the maximum total air quality impacts of SO 2 

### , NO 2 

### , PM 10 

### , PM 2.5 

### , and CO from the existing Units 1 through 4 added to background concentrations. A summary of the maximum total air quality predic ted for comparison to the AAQS in the Plant’s vicinity is presented in Table 6-4. These resu lts 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 SO 2 

### concentrations are predicted to be 32, 221, and 604 micrograms per cubic meter (μg/m 3 

### ), respectively. These concentrations are below the
annual, 24 hour, and 3 hour SO 2 

### AAQS of 60, 260, and 1,300 μg/m 3 

### , respectively.

The highest annual NO 2 

### concentration is predicted to be 21μg/m 3 

### , which is below the annual NO x 

### AAQS of 100 μg/m 3



### .January 2012 6-9 113-87618

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### The highest annual and HSH 24 hour PM 10 

### concentrations are 19 and 56 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 10 

### AAQS of 50 and 150 μg/m 3 

### , respectively.

The highest annual and 24 hour PM 2.5 

### concentrations are 8 and 21 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 2.5 

### AAQS of 15 and 35 μg/m 3 

### , respectively.

The HSH 8 hour and HSH 1 hour CO concentrati ons are predicted to be 2,314 and 3,203 μg/m 3



### , respectively. These concentrations are below th e 8 hour and 1 hour CO AAQS of 10,000 and 40,000 μg/m 3 

### , respectively. It should be noted that the b ackground 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 fo r PEEC for the CTs firing natural gas and fuel oil are given in Table 6-5 for impacts in the Plan t’s vicinity. Based on the worst-case operating condition, two additional modeling analyses were perfo rmed. 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 th e 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 th ese 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 SO 2 

### concentrations are predicted to be 3, 24, 98, and 106 μg/m 3 

### , respectively. These concentrations are below the annual, 24
hour, 3 hour, and 1 hour SO 2 

### AAQS of 60, 260, 1,300, and 197 μg/m 3 

### , respectively.

The highest annual and 1 hour NO 2 

### concentrations are predic ted to be 13 and 120 μg/m 3 

### , respectively,

which are below the annual and 1 hour NO 2 

### AAQS of 100 and 188 μg/m 3 

### , respectively.

The highest annual and 24 hour PM 10 

### concentrations are 19 and 54 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 10 

### AAQS of 50 and 150 μg/m 3 

### , respectively.January 2012 6-10 113-87618

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### The highest annual and 24 hour PM 2.5 

### concentrations are 8 and 21 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 2.5 

### AAQS of 15 and 35 μg/m 3 

### , respectively.

The highest 8 hour and 1 hour CO concentrati ons are predicted to be 2,333 and 3,219 μg/m 3



### , respectively. These concentrations are below th e 8 hour and 1 hour CO AAQS of 10,000 and 40,000 μg/m 3 

### , respectively. Similar to the air quality im pacts predicted for the existing FPL units, the background concentrations contribute more than 99 percent to the total air quality impacts.

CTs, Fuel Heater, and Natu ral 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 SO 2 

### concentrations are predicted to be 3, 24, 99, and 106 μg/m 3



### , respectively. These concentrations are be low the annual, 24 hour, 3 hour, and 1 hour SO 2 

### AAQS of 60, 260, 1,300, and 197 μg/m 3 

### , respectively.

The highest annual and 1 hour NO 2 

### concentrations are predic ted to be 13 and 123 μg/m 3 

### , respectively,

which are below the annual and 1 hour NO 2 

### AAQS of 100 and 188 μg/m 3 

### , respectively.

The highest annual and 24 hour PM 10 

### concentrations are 19 and 54 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 10 

### AAQS of 50 and 150 μg/m 3 

### , respectively.

The highest annual and 24 hour PM 2.5 

### concentrations are 8 and 21 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 2.5 

### AAQS of 15 and 35 μg/m 3 

### , respectively.

The highest 8 hour and 1 hour CO concentrati ons are predicted to be 2,334 and 3,220 μg/m 3



### , respectively. These concentrations are below th e 8 hour and 1 hour CO AAQS of 10,000 and 40,000 μg/m 3 

### , 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 auxilia ry 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

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### The highest annual, 24 hour, 3 hour, and 1 hour SO 2 

### concentrations are predicted to be 2.6, 22, 96, and 104 μg/m 3 

### , respectively. These concentrations are be low the annual, 24 hour, 3 hour, and 1 hour

SO 2 

### AAQS of 60, 260, 1,300, and 197 μg/m 3 

### , respectively.

The highest annual and 1 hour NO 2 

### concentrations are predicted to be 12 and 120 μg/m 3 

### , which are

below the annual NO x 

### AAQS of 100 and 188 μg/m 3 

### , respectively.

The highest annual and 24 hour PM 10 

### concentrations are 18 and 51 μg/m 3 

### , respectively. These

concentrations are below the annual and 24 hour PM 10 

### AAQS of 50 and 150 μg/m 3 

### , respectively.

The highest 8 hour and 1 hour CO concentrati ons are predicted to be 2,329 and 3,238 μg/m 3



### , respectively. These concentrations are below th e 8 hour and 1 hour CO AAQS of 10,000 and 40,000 μg/m 3 

### , 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 SO 2 

### , NO 2 

### , PM 10 

### , and PM 2.5 

### 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 ar e much lower than tho se for existing Units 1 through 4.

6.3 Conclusions

Based on these air quality modeling analyses, the ma ximum 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 qualit y 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 SO 2 

### and PM 10 

### 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 Atmosphe ric 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). Resear ch Triangle Park, North Carolina. U.S. Environmental Protection Agency. 1993. “Alternative Control Techniques Document—NO x 

### 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.

## TABLESJanuary 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 SO 2 lb/hr 17.0 16.3 15.8 15.2
PM/PM 10 /PM 2.5 lb/hr 8.4 8.1 7.8 7.5
NO x 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 SO 2 lb/hr 13.7 13.0 12.6 12.0
PM/PM 10 /PM 2.5 lb/hr 6.8 6.5 6.3 6.0
NO x 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 SO 2 lb/hr 10.4 9.9 9.6 9.2
PM/PM 10 /PM 2.5 lb/hr 5.3 5.1 4.9 4.8
NO x 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.xlsxtab2-1AJanuary 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
SO 2 lb/hr 15.6 14.9 14.3 13.7
PM/PM 10 /PM 2.5 lb/hr 15.1 13.9 13.7 12.6
NO x 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
SO 2 lb/hr 12.9 12.0 11.6 10.9
PM/PM 10 /PM 2.5 lb/hr 12.4 11.2 11.0 10.9
NO x 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
SO 2 lb/hr 10.5 9.9 9.5 9.0
PM/PM 10 /PM 2.5 lb/hr 10.7 10.6 10.5 10.4
NO x 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:tab2-1BJanuary 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 SO 2 lb/hr 4.0 3.7 3.6 3.4
PM/PM 10 /PM 2.5 lb/hr 20.8 19.8 19.2 18.4
NO x 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 SO 2 lb/hr 3.2 3.1 2.9 2.8
PM/PM 10 /PM 2.5 lb/hr 17.0 16.3 15.7 15.1
NO x 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 SO 2 lb/hr 2.8 2.7 2.6 2.5
PM/PM 10 /PM 2.5 lb/hr 14.5 13.9 13.5 13.0
NO x 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.xlsxtab2-2AJanuary 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 SO 2 lb/hr 4.1 3.9 3.8 3.6
PM/PM 10 /PM 2.5 lb/hr 60.1 57.0 55.0 51.9
NO x 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 SO 2 lb/hr 3.4 3.2 3.1 2.9
PM/PM 10 /PM 2.5 lb/hr 48.9 46.8 44.8 42.8
NO x 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 SO 2 lb/hr 3.1 2.9 2.8 2.7
PM/PM 10 /PM 2.5 lb/hr 43.8 42.8 40.7 39.7
NO x 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 DAT A TABLE 2-2B

Operating and Emission Data a for Ambient Temperature FOR THE COMBUSTION TURBINES/HRSGS - ULTRA LOW-SULFUR DISTILLATE OIL COMBUSTION, SIEMENS H C T

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:tab2-2BJanuary 2012113-87618OperatingScenarioNat Gas 100 % Load 8,760 7,760 0 3,880 0 3,880Fuel Oil 100 % Load 0 1,000 0 1,000 0 1,000Nat Gas 80 % Load 0 0 8,760 3,880 0 0Fuel Oil 80 % Load 0 0 0 0 0 0Nat Gas 60 % Load 0 0 0 0 8,760 3,880Nat Gas Fuel Oil Nat Gas Fuel Oil Nat Gas Fuel Oil Fuel Oil 70 % Load 0 0 0 0 0 075 °F 75 °F 75 °F 75 °F 75 °F 75 °FPollutant100% 100% 75% 75% 50% 50% TOTAL8,760 8,760 8,760 8,760 8,760 8,760One Combustion TurbineSO215.8 3.6 12.6 2.9 9.6 2.669.2 63.1 55.0 56.8 42.0 51.1PM/PM10/PM2.57.8 19.2 6.3 15.7 4.9 13.534.3 40.0 27.5 36.9 21.7 34.4NOx19.8 70.6 15.5 57.7 11.8 50.386.9 112.3 67.8 103.8 51.9 96.7CO54.3 187.9 42.4 153.7 32.4 134.0238.0 304.8 185.7 281.6 142.0 262.3VOC (as methane)3.5 30.7 2.7 25.1 2.1 21.915.1 28.7 11.8 27.3 9.0 26.0Sulfuric Acid Mist3.1 0.7 2.4 0.6 1.9 0.513.5 12.3 10.7 11.1 8.2 9.9Lead0.0 0.033 0.0 0.027 0.0 0.0230.0 0.016 0.0 0.016 0.0 0.016HAPs1.23 2.90 0.98 2.38 0.75 2.075.4 6.2 4.3 5.7 3.3 5.3Three Combustion TurbinesSO247.4 11 37.7 9 28.8 8208 189 165 170 126 153PM/PM10/PM2.523.5 58 18.8 47 14.8 41102.8 119.9 82.4 111 65 103NOx59.5 212 46.4 173 35.5 151261 337 203 311 156 290CO163.0 564 127.2 461 97.3 402714 914 557 845 426 787VOC (as methane)10.4 92.0 8.1 75.3 6.2 65.645.3 86.2 35.4 81.8 27.1 78.1Sulfuric Acid Mist9.2 2.1 7.3 1.7 5.6 1.540.4 36.8 32.1 33.2 24.5 29.8Lead0.00 0.10 0.00 0.08 0.00 0.070.00 0.049 0.00 0.049 0.00 0.049HAPs3.69 8.69 2.93 7.13 2.24 6.2216.2 18.7 12.9 17.2 9.8 15.9Sources: MPS, 2011; Golder, 2011.- Fuel for Ambient Temperature & LoadTABLE 2-3ASUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR THE CTS/HRSGS, MPS 501J CTSMaximum Emissions (tons/year)Operating HoursMaximum Hourly Emissions (lb/hr)Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:tab2-3AJanuary 2012113-87618OperatingScenarioNat Gas 100 % Load 8,760 7,760 0 3,880 0 3,880Fuel Oil 100 % Load 0 1,000 0 1,000 0 1,000Nat Gas 80 % Load 0 0 8,760 3,880 0 0Fuel Oil 80 % Load0 0 0 000Nat Gas 60 % Load00008,760 3,880Nat Gas Fuel Oil Nat Gas Fuel Oil Nat Gas Fuel Oil Fuel Oil 70 % Load0 0 0 00075 °F 75 °F 75 °F 75 °F 75 °F 75 °FPollutant 100% 100% 80% 80% 60% 70% TOTAL 8,760 8,760 8,760 8,760 8,760 8,760One Combustion TurbineSO214.3 3.8 11.6 3.1 9.5 2.862.5 57.2 50.8 52.1 41.7 48.0PM/PM10/PM2.513.7 55.0 11.0 44.8 10.5 40.760.2 80.8 48.4 75.6 46.0 74.5NOx19.4 81.0 15.8 66.3 13.0 60.685.1 115.9 69.4 108.9 56.8 103.3CO30.0 62.0 48.0 50.0 40.0 46.0131.4 147.4 210.2 182.3 175.2 166.8VOC (as methane)3.4 35.0 2.8 29.0 2.3 26.014.9 30.7 12.3 29.5 10.1 28.6Sulfuric Acid Mist2.8 0.73 2.3 0.60 1.9 0.5512.1 11.1 9.9 10.1 8.1 9.3Lead0.00 0.034 0.00 0.028 0.00 0.0260.0 0.017 0.0 0.017 0.0 0.017HAPs1.15 3.08 0.94 2.52 0.77 2.315.1 6.0 4.1 5.6 3.4 5.3Three Combustion TurbinesSO242.8 11 34.8 9.2 28.6 8.4187 172 152 156 125 144PM/PM10/PM2.541.2 165 33.1 134 31.5 122180.5 242.4 145.1 227 138 224NOx58.3 243 47.5 199 38.9 182255 348 208 327 170 310CO90.0 186 144.0 150 120.0 138394 442 631 547 526 500VOC (as methane)10.2 105.0 8.4 87.0 6.9 78.044.7 92.1 36.8 88.6 30.2 85.7Sulfuric Acid Mist8.3 2.2 6.8 1.8 5.6 1.636.4 33.4 29.6 30.4 24.4 28.0Lead0.00 0.103 0.00 0.084 0.00 0.0770.000 0.052 0.000 0.052 0.000 0.052HAPs3.46 9.23 2.82 7.56 2.31 6.9215.16 18.04 12.33 16.8 10.1 15.8Sources: Siemens, 2011; Golder, 2011.- Fuel for Ambient Temperature & LoadTABLE 2-3BOperating HoursSUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR THE CTS/HRSGS, SIEMENS H CTSMaximum Emissions (tons/year)Maximum Hourly Emissions (lb/hr)Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:tab2-3B 1000hrOILJanuary 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
SO 2 -Basis b grains S/100 scf 2 Emissions lb/hr 0.56
TPY 0.56

NO x - 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/PM 10 /PM 2.5 - 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxt ab2-4 AuxBlrJanuary 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 SO 2 - Basis %S 0.0015%
Conversion of S to SO 2 % 100 Molecular weight SO 2 / S (64/32) 2 Emission rate lb/hr 0.032 0.065 TPY 0.0016 0.0032

NO x - 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/PM 10 /PM 2.5 - 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxT ab2-5 E GenJanuary 2012 113-87618

Parameter Units Values

Performance a Number of Units 1 Fuel N atural gas Heat Input (HHV) MMBtu/h r 9.90 Heat Content (HHV-Btu/scf) Btu/sc f 1,020 Fuel Usage scf/h r 9,706 Maximum operation/yr hours 8,760 Maximum Fuel Usag e MMscf/y r 85.0

Stack Parameters (typical) Diamete r f t 1.4 Heigh t f t 30 Temperature o F 500 Velocity ft/sec 53.6 Flo w acf m 4,950

Emissions
SO 2 -Basis b grains S/100 scf 2 Emissions lb/MMBtu 0.0056 lb/h r 0.055 TPY 0.24

NO x - Basis c lb/MMscf 100 Emission rate lb/MMBtu 0.098 lb/h r 0.97 TPY 4.25

CO - Basis c lb/MMscf 84 Emission rate lb/MMBtu 0.082 lb/h r 0.82 TPY 3.57

VOC - Basis c lb/MMscf 5.5 Emission rate lb/MMBtu 0.0054 lb/h r 0.053 TPY 0.23

PM/PM 10 /PM 2.5 - Basis c,d lb/MMscf 7.6 Emission rate lb/MMBtu 0.0075 lb/h r 0.074 TPY 0.32

N ote: 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 HEATE R

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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 SO 2 - Basis %S 0.0015%
Conversion of S to SO 2 % 100 Molecular weight SO 2 /S (64/32) 2
Emission rate lb/hr 0.0036
TPY 0.00018

NO x - 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/PM 10 /PM 2.5 - 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxT ab2-7 FirePumpJanuary 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
SO 2 - Basis grains/100 scf 2 2 2 2
Conversion of S to SO 2 100 100 100 100 Ratio Molecular weight SO 2 / 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

NO x - 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/PM 10 /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

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxT ab2-8 CentaurJanuary 2012113-876183Maximum 2-Year PSDCTs/HRSGs 1 2 1 2 1 Fuel Oil Average from Significantwith Auxiliary Emergency Natural Gas Gas Fire Pump Storage Existing Units 1 to 4cChange Emission RatePollutant Duct BurnersaBoilerbGenerators Heater Compressors Engine Tank TOTAL(TPY)(TPY)(TPY)SO22080.56 0.003 0.24 2.60 0.00018 NA 2119,494-9,28340PM1200.74 0.28 0.32 2.98 0.013 NA 124604-47925PM101200.74 0.28 0.32 2.98 0.013 NA 124604-47915PM2.51200.74 0.28 0.32 2.98 0.01 NA 124402-27810NOx3374.99 4.87 4.25 25.2 0.22 NA 3764,260-3,88440CO9147.98 6.00 3.57 25.6 0.086 NA 95888573100VOC (as methane)86.2 0.54 0.71 0.237.3 0.033 5.82 100.876.923.840Sulfuric Acid Mist40.4 Neg. Neg. Neg. Neg. Neg. NA 40.4422.3-3827Lead0.049 Neg. Neg. Neg. Neg. Neg. NA 0.0490.10-0.0490.6Greenhouse Gases (CO2e) 4,410,327 11,670 687 5,072 55,313 15.2 NA 4,483,0852,551,0381,932,047 75,000aBased on oil-firing for:1,000bAn auxiliary boiler is onlyrequired to supply steam to the MPS 501J CT during startup.cBased 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 CalculationsTABLE 2-9ASUMMARY OF MAXIMUM POTENTIAL ANNUALEMISSIONS FOR PEEC, MPS 501J CTSPEEC ProjectY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab2-9A MHI501JJanuary 2012113-87618Maximum 2-YearPSD2121 Fuel OilAverage fromSignificant3 Emergency Natural Gas Gas Fire Pump StorageExisting Units 1 to 4bChange Emission RatePollutantCTs/HRSGsaGenerators Heater Compressors Engine Tank TOTAL(TPY)(TPY) (TPY)SO21870.003 0.24 2.60 0.00018 NA 1909,494-9,30440PM2420.28 0.32 2.98 0.013 NA 246604-35825PM102420.28 0.32 2.98 0.013 NA 246604-35815PM2.52420.28 0.32 2.98 0.013 NA 246402-15610NOx3484.87 4.25 25.2 0.22 NA 3824,260-3,87840CO6316.00 3.57 25.6 0.086 NA 666885-219100VOC (as methane)92.10.71 0.237.3 0.033 5.82 10676.929.240Sulfuric Acid Mist36.4Neg. Neg. Neg. Neg. NA 36.4422.3-3867Lead0.052Neg. Neg. Neg. Neg. NA 0.0520.10-0.0470.6Greenhouse Gases (CO2e)4,058,754 687 5,072 55,313 15.2 NA 4,119,841.35 2,551,038 1,568,804 75,000aBased on oil-firing for:1,000bBased on actual emissions from Annual Operating Reports from 2006-2010.Note: Neg.= negligible; NA= not applicablehours (maximum).Maximum Potential Annual Emissions (TPY) Netting CalculationsTABLE 2-9BSUMMARY OF MAXIMUM POTENTIAL ANNUAL EMISSIONS FOR PEEC, SIEMENS H CTSPEEC ProjectSource: 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 SiemensJanuary 2012113-87618HAP Major12 1 2 1Fuel OilSource3Auxiliary Emergency Natural Gas Gas Fire Pump StorageThresholdPollutant CTs/HRSGsBoilerbGenerators Heater Compressors Engine Tank TOTAL (TPY)MPS 501J CTsTotal HAPs18.70.0088 0.003 0.004 0.45 0.0002 NA 19.1 25Single HAPa7.90.0073 0.0002 0.003 0.34 0.00001 NA 8.210Siemens H CTsTotal HAPs18.0NA 0.003 0.004 0.45 0.0002 NA 18.5 25Single HAPa6.9NA 0.0002 0.003 0.34 0.00001 NA 7.310aBased on formaldehyde emissionsbAn auxiliary boiler is only required to supply steam to the MPS 501J CT during startup.Note: NA= not applicable.Source: Golder, 2011.TABLE 2-10SUMMARY OF MAXIMUM POTENTIAL ANNUAL HAP EMISSIONS FOR PEECMaximum Potential Annual Emissions (TPY)Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsxTab 2-10 HAPStotalJanuary 2012113-87618Pollutant Averaging TimePrimaryStandardSecondaryStandard Florida AAQS(μg/m3)Class I Class II Class I Class IIParticulate Matter Annual Arithmetic Mean NA NA 50 4 17 0.2 1(PM10)a24-Hour Maximum1501501504300.35Particulate Matter Annual Arithmetic Mean151515140.060.3(PM2.5)a24-Hour Maximum353535290.071.2Sulfur DioxidebAnnual Arithmetic Mean80NA602200.1124-Hour Maximum365NA2605910.253‐Hour MaximumNA1,3001,300255121251‐Hour Maximum197NANANANANA7.9eCarbon Monoxide 8‐Hour Maximum 10,000 10,000 10,000 NA NA NA 5001‐Hour Maximum 40,000 40,000 40,000 NA NA NA 2,000Nitrogen DioxidecAnnual Arithmetic Mean1001001002.5250.111‐Hour Maximum188NANANANANA7.6eOzoned1‐Hour Maximum NA NA 235 NA NA NA NA8-Hour Maximum 147 147 NA NA NA NA NALead Rolling 3-Month Average 0.15 0.15 0.15 NA NA NA NANote: NA = not applicable.AAQS = ambient air quality standard.aOn October 17, 2006, EPA promulgated revised PM10and PM2.5AAQS; the PM2.5AAQS had been promulgated on July 18, 1997. For PM10, the annual standard was revoked and the 24-hour standard was retained.The 24-hour PM2.5standard was revised to 35 μg/m3based on the 3-year averages of the 98th percentile values. The annual PM2.5standard of 15 μg/m3, 3-year averages at community monitors, was retained.bOn June 23, 2010, EPA promulgated the 1-hour SO2standard 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 concentrations(effective August 23, 2010). EPA is also revoking both the existing 24-hour and annual primary SO2standards, effective one year after the designation of an area, pursuant to section 107 of the Clean Air Act.cOn February 9, 2010, EPA promulgated the 1-hour NO2standard at a level of 100 ppb, based on the 3-year average of the annual 99th percentile of 1-hour daily maximum concentrations (effective April 12, 2010).dOn March 27, 2008, EPA promulgated revised AAQS for ozone. The O3standard was modified to be 0.075 ppm (147 μg/m3) for the 8-hour average; achieved when the 3-year average of 99th percentile values is 0.075 ppm or less.eFor NO2and SO21-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 3-1NATIONAL AND STATE AAQS, ALLOWABLE PSD INCREMENTS, AND SIGNIFICANT IMPACT LEVELSAAQS (μg/m3)PSDIncrements (μg/m3)Significant ImpactLevels (μg/m3)NationalY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Tables\Table 3-1 AAQS.xlsx:Tab3-1 AAQSJanuary 2012 113-87632

Significant De Minimis Emission Monitoring Regulated Rate Concentration Pollutant Under (TPY) (μg/m 3 ) a

Sulfur Dioxide NAAQS, NSPS 40 13, 24-hour Particulate Matter [PM(TSP)] NSPS 25 NA

Particulate Matter (P M 10 ) NAAQS 15 10, 24-hour Particulate Matter (P M 2.5 ) c NAAQS 10, or 4, 24-Hour NAAQS 40 of SO 2 , o r NA NAAQS 40 of NO x NA Nitrogen Dioxide NAAQS, NSPS 40 14, annual Carbon Monoxide NAAQS, NSPS 100 575, 8-hour Volatile Organic Compounds (Ozone) NAAQS, NSPS 40 100 TPY b

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 (SO 2 + HCl) NSPS 40 NM MSW Landfill Gases (as NMOC) NSPS 50 NM
Greenhouse Gases d -- 0 (mass basis), and NM

-- 75,000 (CO 2 e 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 N M = no ambient measurement method established; therefore, no de minimis
concentration has been established mg/m 3 = micrograms per cubic meter MWC = municipal waste combusto r 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 NO x 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 CO 2 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 CH ANGES 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 (PM 10 

### )

− 358 15 No Particulate Matter (PM 2.5 

### )

− 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 SO 2 

### :

 100-percent load, natural gas – 7,760 hours

 100-percent load, oil firing – 1,000 hours

B. SO 2 

### 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 bo iler, fire pump engine, fuel oil storage tank, and gas compressor sta tion (see Tables 2-9A and B, which present the maximum potential emissions for PEEC) and em ission reductions from the existing Units 1 through 4 at Port Everglades Plant.January 2012113-87618Operating ProposedPollutant CT(s) Fuel Mode Emission Limits Compliance MethodsNOxJ and H Natural Gas All2 ppmvd at 15% O2Initial: EPA Methods- 7E or 20, Continuous: CEM 30-day rolling averageJ and H ULSD All 8 ppmvd at 15% O2Initial: EPA Methods- 7E or 20, Continuous: CEM 30-day rolling averageCO J Natural Gas Baseload 9 ppmvd at 15% O2Initial: EPA Method 10ULSD Baseload 35 ppmvd at 15% O2Initial: EPA Method 10H Natural Gas Baseload 5 ppmvd at 15% O2Initial: EPA Method 10ULSD Baseload 10 ppmvd at 15% O2Initial: EPA Method 10VOC J Natural Gas Baseload 1 ppmvd at 15% O2Initial Only: EPA Methods 18 or 25aULSD Baseload 10 ppmvd at 15% O2Initial Only: EPA Methods 18 or 25aH Natural Gas Baseload 1 ppmvd at 15% O2Initial Only: EPA Methods 18 or 25aULSD Baseload 10 ppmvd at 15% O2Initial Only: EPA Methods 18 or 25aPM/PM10J and H Natural Gas All10% OpacityInitial/Annual: EPA Method 9J and H ULSD All10% OpacityInitial/Annual: EPA Method 9SO2and SAM J and H Natural Gas All2 grains S/100 scf Initial/Annual: 40 CFR Part 75 Fuel SamplingJ and H ULSD All0.0015% SInitial/Annual: 40 CFR Part 75 Fuel SamplingGHG J and H Natural Gas All877 lb CO2e/MW-hr 12-month rolling average; CO2ebased on 40 CFR Part 98, Subpart C& ULSDMW-hr based on 40 CFR Part Subpart KKKKNote: CT = combustion turbine; HRSG = heat recovery steam generator; ULSD = ultra low sulfur distillate light oil.J = MPS 501J CT; H = Siemens H CT.TABLE 4-1PROPOSED EMISSION LIMITS FOR CTS/HRSGS FOR PEECY:\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.xlsxJanuary 2012113-876183-Hour 8-Hour 8-Hour AnnualPollutant/3-yearAIRS Measurement Period 2nd 2nd 2nd Average 2ndSite No. Location County Year Months Highest Highest Percentile Highest Highest Highest Highest 4th Highest Highest Highest Percentile AverageSulfur dioxide (SO2)cFlorida AAQSNA NA 0.075 ppm NA 0.5 ppm NA NA NA NA 0.1 ppm0.02 ppm99th12-011-0010Fort Lauderdale,Broward 2010 Jan-Dec 0.076 0.056 0.038-- -- NA NA NA 0.015 0.0059 NA 0.0004Lincoln Park Elementary School2009 Jan-Dec 0.096 0.072 --0.057 0.057 NA NA NA 0.015 0.014 NA 0.00152008 Jan-Dec 0.031 0.021 --0.019 0.014 NA NA NA 0.005 0.004 NA 0.0011Nitrogen dioxide (NO2)dFlorida AAQSNA NA 0.1 ppm NA NA NA NA NA NA NA0.053 ppm98th12-011-8002DaniaBroward 2010 Jan-Dec 0.065 0.054 0.049NANA NA NA NA NA NA NA 0.00717000 N. Ocean Drive2009 Jan-Dec 0.066 0.050 --NANA NA NA NA NA NA NA 0.00652008 Jan-Dec 0.058 0.055 --NANA NA NA NA NA NA NA 0.0053Particulate Matter (PM10)aFlorida AAQSNA NANANA NA NA NA NA 150 μg/m350 μg/m312-011-0010Fort Lauderdale,Broward 2010 Jan-Dec NA NA NA NANA NA NA NA 37 32 NA15.4Lincoln Park Elementary School2009 Jan-Dec NA NA NA NANA NA NA NA 4943 NA14.12008 Jan-Dec NA NA NA NANA NA NA NA 5041 NA18.712-011-3002HollywoodBroward 2009 Jan-Dec NA NA NA NANA NA NA NA 35 34 NA17.62701 Plunkett Street2008 Jan-Dec NA NA NA NANA NA NA NA 8264 NA18.5NAParticulate Matter (PM2.5)aFlorida AAQSNA NANANA NA NA NA NA NA 35 μg/m3 15 μg/m398th12-011-2003Pompano BeachBroward 2010 Jan-Dec NA NA NA NANA NA NA NA 13.5 12.2 12.26.691951 NE 48th Street2009 Jan-Dec NA NA NA NANA NA NA NA 14.7 13.0 12.37.092008 Jan-Dec NA NA NA NANA NA NA NA 28.2 26.1 18.37.2912-011-3002HollywoodBroward 2009 Jan-Dec NA NA NA NANA NA NA NA 10.2 10.2 10.26.472701 Plunkett Street2008 Jan-Dec NA NA NA NANA NA NA NA 30.0 24.5 21.87.69Ozone (O3)bFlorida AAQSNA 0.12 ppmNANA NA NA 0.075 ppm NA NANA12-011-8002DaniaBroward 2010 Jan-Dec 0.107 0.074 NA NANA NA NA 0.069 NA NA NANA7000 N. Ocean Drive2009 Jan-Dec 0.077 0.073 NA NANA NA NA 0.069 NA NA NANA2008 Jan-Dec 0.083 0.082 NA NANA NA NA 0.069 NA NA NANACarbon monoxide (CO)Florida AAQSNA 35 ppmNANA NA 9 ppmNA NA NANA12-011-0010Fort Lauderdale,Broward 2010 Jan-Dec2.32.3 NA NANA 1.8 1.6NA NA NA NANALincoln Park Elementary School2009 Jan-Dec3.12.8 NA NANA 2.0 1.9NA NA NA NANA2008 Jan-Dec3.23.2 NA NANA 2.5 2.5NA NA NA NANA12-011-3002HollywoodBroward 2009 Jan-Dec1.81.8 NA NANA 1.5 1.5NA NA NA NANA2701 Plunkett Street2008 Jan-Dec2.42.1 NA NANA 1.7 1.6NA NA NA NANANote: NA = not applicable.AAQS = ambient air quality standard.aOn October 17, 2006, EPA promulgated revised PM10and PM2.5AAQS; the PM2.5AAQS had been promulgated on July 18, 1997. For PM10, the annual standard was revoked and the 24-hour standard was retained.The 24-hour PM2.5standard was revised to 35 μg/m3based on the 3-year averages of the 98th percentile values. The annual PM2.5standard of 15 μg/m3, 3-year averages at community monitors, was retained.bOn March 27, 2008, EPA promulgated revised AAQS for ozone. The O3standard was modified to be 0.075 ppm for the 8-hour average; achieved when the 3-year average of 99th percentile values is 0.08 ppm or less.cOn June 23, 2010, EPA promulgated the 1-hour SO2standard 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 concentrations (effective August 23, 2010).EPA is also revoking both the existing 24-hour and annual primary SO2standards, effective one year after the designation of an area, pursuant to section 107 of the Clean Air Act.dOn February 9, 2010, EPA promulgated the 1-hour NO2standard at a level of 100 ppb, based on the 3-year average of the annual 99th percentile of 1-hour daily maximum concentrations (effective April 12, 2010).TABLE 5-1SUMMARY OF MAXIMUM MEASURED SO2, NO2, PM10, PM2.5, O3, AND CO CONCENTRATIONSREPRESENTATIVE OF PEEC PROJECT, 2008 THROUGH 2010Measured Concentration1-Hour24-HourY:\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 MonitoringDataJanuary 2012113-87618Ambient AirQuality StandardAveraging Existing(AAQS)Pollutant Time Units 1, 2, 3 & 4 OnlyPEEC OnlybUnits 1, 2, 3 & 4PEECb(μg/m3)SO2Annual29.80.432.43.06024-Hour2003.322124.22603-Hour5115.560498.51,3001-HourNA6.0NA106197PM10Annual1.10.619.118.75024-Hour6.84.955.853.9150PM2.5Annual0.70.67.87.71524-Hour4.54.920.520.935NO2Annual9.31.421.113.31001-HourNA30.8NA123188CO8-Hour14.234.023142,33410,0001-Hour21.138.332033,22040,000aBackground concentration based on the maximum measured concentration from representative air quality data for the Site.bPEEC sources include the 3 CTs/HRSGs, fuel heater, and gas compressors.TABLE 6-1SUMMARY OF PREDICTED POLLUTANT CONCENTRATIONSFOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT AND THE PEEC PROJECTCOMPARED TO AMBIENT AIR QUALITY STANDARDSMaximum Concentration (ug/m3)Total Concentration (ug/m3)including BackgroundaY:\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 AE RMOD MODEL, VERSION 11 353

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 atmosphe re uses a mechanically mixed layer near the surface.

• Polar or Cartesian coordinate syst ems 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, vo lume, 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 characteris tics are determined by selected di rection 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 da ta for the processing of short term averages.

Note: AERMOD = The American Mete orological 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 input b 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
SO 2 lb/MMBtu b 1.10 1.10 1.10 1.10 lb/hr 2,530 2,530 4,400 4,400

PM/PM 10 lb/MMBtu a,c 0.039 0.039 0.039 0.039 lb/hr 89 89 155 155

PM 2.5 lb/MMBtu e 0.026 0.026 0.026 0.026 lb/hr 59 59 103 103

NO x 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 ExistingDataJanuary 2012113-87618Ambient AirQuality StandardAveraging ConcentrationExisting(AAQS)Pollutant TimeRankUnits 1, 2, 3 & 4 Only BackgroundTotal(μg/m3)SO2AnnualHighest29.82.632.46024-Hour Highest, 2nd-Highest20020.92212603-Hour Highest, 2nd-Highest51193.06041,300PM10AnnualHighest1.118.119.15024-Hour Highest, 6th-Highest6.849.055.8150PM2.5AnnualHighest0.77.17.81524-Hour Highest, 6th-Highest4.516.020.535NO2AnnualHighest9.311.921.1100CO8-Hour Highest, 2nd-Highest14.22,3002,31410,0001-Hour Highest, 2nd-Highest21.13,1823,20340,000TABLE 6-4SUMMARY OF PREDICTED POLLUTANT CONCENTRATIONSFOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANTCOMPARED TO AMBIENT AIR QUALITY STANDARDSMaximum 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 ImpactsJanuary 2012 113-87618

Averaging
Pollutant Time Natural Gas Fuel Oil Maximum Natural Gas Fuel Oil Maximum

CTs Only a
SO 2 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

PM 10 /PM 2.5 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

NO 2 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

SO 2 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

PM 10 /PM 2.5 Annual NM 0.22 0.22 NM 0.63 0.63 24-Hour NM 1.81 1.81 NM 4.95 4.95

NO 2 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

SO 2 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

PM 10 /PM 2.5 Annual NM 0.25 0.25 NM 0.63 0.63 24-Hour NM 1.81 1.81 NM 4.95 4.95

NO 2 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

SO 2 8,760 0 8,760
PM 10 /PM 2.5 7,760 1,000 8,760
NO 2 7,760 1,000 8,760

b

c NO x to NO 2 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/m 3 ) Maximum Predicted MPS J CTs Siemens H CTs
Maximum Predicted Concentration (μg/m 3 )

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 Tab6-5January 2012 113-87618

Averaging AAQS
Pollutant Time PEEC a Background b Total PEEC a Background b Total (μg/m 3 )

CTs and Fuel Heater SO 2 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

PM 10 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

PM 2.5 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

NO 2 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 SO 2 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

PM 10 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

PM 2.5 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

NO 2 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/m 3 ) Concentration (μg/m 3 ) 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 Tab6-6January 2012113-87618Ambient AirMaximum Background Total Quality StandardEmission AveragingConcentrationa,dConcentrationbConcentration(AAQS)PollutantRate Units Time(ug/m3)(ug/m3)(ug/m3)(ug/m3)SO20.56 TPY Annual0.0332.62.6600.56 lb/hr 24-Hour1.420.922.32600.56 lb/hr 3-Hour2.893.095.81,3000.56 lb/hr 1-Hour3.999.6103.5197PM100.74 TPY Annual0.0418.118.1500.74 lb/hr 24-Hour1.849.050.8150PM2.50.74 TPY Annual0.047.17.1500.74 lb/hr 24-Hour1.816.017.8150NOxc4.99 TPY Annual0.2211.912.11004.99 lb/hr 1-Hour27.992.2120.1188CO7.98 lb/hr 8-Hour28.82,3002,32910,0007.98 lb/hr 1-Hour55.83,1823,23840,000aConcentrations are based on highest concentrations predicted using 5 years of meteorological data from 2006 to 2010 of surface and upper air datafrom 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 pollutantspecific rate:ModeledPredictedRateAveragingConcentration(lb/hr)Time(ug/m3)79.37 Annual 20.424-Hour 197.28-Hour 286.13-Hour 393.91-Hour 555.3bBased on highest concentrations measured at representative monitoring stations nearest the site.cNOxto NO2conversion factor of 0.75 and 0.80 applied to modeled annual and 1-hour NOximpacts, respectively, based on EPA Modeling Guidelines.dBased on 2,000 hours/yr operation.TABLE 6-7SUMMARY OF POLLUTANT CONCENTRATIONS PREDICTED FOR THE PEEC AUXILIARY BOILERCOMPARED TO EPA AMBIENT AIR QUALITY STANDARDSY:\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 Tab6-7January 2011 113-87618

Averaging Existing Pollutant Time MPS J CTs Siemens H CTs Units 1 - 4

SO 2 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

PM 10 Annual 0.0038 0.011 0.028 24-Hour 0.055 0.16 0.37

PM 2.5 Annual 0.0038 0.011 0.028 24-Hour 0.055 0.16 0.37

NO 2 Annual b 0.011 0.012 0.25

1-Hour b 1.73 1.93 30.6

SO 2 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

PM 10 Annual 0.0038 0.011 0.028 24-Hour 0.055 0.16 0.37

PM 2.5 Annual 0.0038 0.011 0.028 24-Hour 0.055 0.16 0.37

NO 2 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 NO 2 and PM 10 /PM 2.5 , oil-firing; for SO 2 , natural gas-firing.

b NO x to NO 2 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/m 3 )

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)

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Port Everglades Plant and Port Everglades Energy Center SiteF:\PROJECTS\2011 PROJ\113-87618_PortEvergladesEnergyCenterSCA\A_0100_Preparation_of_SCA\MapDocuments\113-87618A007 FEMA.mxd 

# 3

7 0 3.5

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REVIEW DESIGN SCALE:

CHECK 0 FILE No. 113-87618A028 PROJECT No. 113-87618

NRL AS SHOWN RCM

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 1/13/2012Process Flow LegendSolid/LiquidGasSteamNovember 2011113-87618Figure 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.COMBUSTORCOMBUSTION TURBINE(CT)NATURAL GASOR ULTRALOW-SULFURLIGHT OILHeat Recovery SteamGenerator (HRSG)GENERATORELECTRICITYAIRHRSGEXHAUSTWATER FORNOXCONTROL(LIGHT OIL)STEAM TOSTEAM/ELECTRICGENERATORParametersUnits Fuel MPS 501J Class Siemens H ClassInlet Airlb/hrGas 4,625,400 4,696,101lb/hrOil 4,639,600 4,767,933CT Heat Input MMBtu/hr (HHV) Gas 2,8192,538MMBtu/hr (HHV) Oil2,3342,453HRSG Velocityft/sec Gas57.358.2ft/secOil70.972.8HRSG TemperatureoFGas195195oF Oil355355HRSG Stack Height feet Gas/Oil 149149HRSG Stack Diameter feet Gas/Oil 2222112233Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Fig 2-2.vsd333January 2012January 2012113-87618Figure 2-3.Comparison of Historical Actual SO2, NOx, and PM Annual Emissions (TPY) for the Existing Units 1 through 4 at Port Everglades PlantCompared to Projected MaximumPotential Annual Emissions (TPY) for PEECY:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\Appx 10.2.5 AC Pmt (PSD)\Figures\Figure 2-3rev1.docxSource: Golder, 2012.01,0002,0003,0004,0005,0006,0007,0008,0009,00010,000SO2NOxPM9,4944,260604211382246

(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 2012113-87618Figure 2-4.Comparison of CO2Emission 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.docxSource: Golder, 2012.02004006008001,0001,2001,4001,6001,800Existing Port Everglades Plant(Units 1 through 4)PEEC (3-on-1)1,738795

(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 2012113-8761813002606060422132.498.524.23.002004006008001000120014003-Hour24-HourAnnual

Concentration (ug/m 3 )Total Air Quality SO2Impacts Predicted for theExisting Units 1 through 4 at Port Everglades Plant and PEECAAQSExisting Units 1-4PEECPEECImpactPEECImpactPEECImpact1505055.819.153.918.702040608010012014016018020024-HourAnnual

Concentration (ug/m 3 )Total Air Quality PM10Impacts Predicted for theExisting Units 1 through 4 at Port Everglades Plant and PEECAAQSExisting Units 1-4PEECPEECImpactPEECImpact10080100120

u g/m 3 )Total Air Quality NO2Impacts Predicted for theExisting Units 1 through 4 Port Everglades Plant and PEECPEECImpact40,00025,00030,00035,00040,00045,000

(ug/m 3 )Total Air Quality CO Impacts Predicted for theExisting Units 1 through 4 Port Everglades Plant and PEECPEECImpactPEECImpact21.113.30204060Annual

Concentration ( uAAQSExisting Units 1-4PEEC10,0003,2032,3143,2202,33405,00010,00015,00020,0001-Hour8-Hour

ConcentrationAAQSExisting Units 1-4PEECFigure 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 AJanuary 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 ( o F + 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/ft 3 ) 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 NO x 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-G100January 2012 113-87618

CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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/m 3 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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 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 SO 2 emission rate (lb/hr) 17.0 16.3 15.8 15.2 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0
DB SO 2 emission rate (lb/hr) -- -- -- -- Conversion (%) from SO 2 to SO 3 in DB -- -- -- -- Remaining SO 2 (lb/hr) after conversion 15.3 14.7 14.2 13.7 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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 co n Basis, ppm actual 46.6 46.4 46.1 45.8 CT/DB, ppmvd @15% O 2 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% O 2 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% O 2 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% O 2 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 co n

Basis, ppm actual 1.33 1.32 1.32 1.31 Basis, ppmvd @ 15% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 17.0 16.3 15.8 15.2
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 (lb/hr)(remaining SO 2 after conversion) 15.3 14.7 14.2 13.7
SCR Conversion to H 2 SO 4 (% 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; O 2 = 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 NO x 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-G100January 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 ( o F + 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/ft 3 ) 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

N ote: 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 NO x 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-G75January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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/m g Emission (mg/m 3 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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 13.7 13.0 12.6 12.0 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 12.3 11.7 11.3 10.8 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 13.7 13.0 12.6 12.0
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 00 0 0
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 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 NO x 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-G75January 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 ( o F + 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/ft 3 ) 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 NO x 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-G50January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate from CT and HRSG Particulate (including PM 2.5 ) from CT and SCR
a. PM 10 (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/m 3 N) 11 1 1 Turbine Flow (acfm) 2,326,538 2,278,198 2,238,039 2,195,120 (m 3 /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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 10.4 9.9 9.6 9.2 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 9.4 8.9 8.6 8.3 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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)(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 6 0 Basis, ppm actual 43.8 42.6 41.6 40.7 CT / DB, ppmvd @15% O 2 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% O 2 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)(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 mi n Basis, ppm actual 11.3 10.9 10.7 10.5 Basis, ppmvd @ 15% O 2 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% O 2 99 9 9 HRSG Stack emission rate (lb/hr) 35.5 33.7 32.4 31.1

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 constant, R) x Actual Temp. (°R)] x 6 0 Basis, ppmvd 1.25 1.22 1.19 1.16 Basis, ppmvd @ 15% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 10.4 9.9 9.6 9.2
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0 0 0 0
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after con v 9.4 8.9 8.6 8.3
SCR Conversion to H 2 SO 4 (% 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 NO x COMBUSTOR, NATURAL GAS, 50% LOAD

Turbine Inlet Temperature

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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 ( o F + 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 NO x 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-O100January 2012 113-87618

Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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/m 3 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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 4.0 3.7 3.6 3.4 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 3.6 3.4 3.2 3.1 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 4.0 3.7 3.6 3.4
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversi o 3.6 3.4 3.2 3.1
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x COMBUSTOR, DISTILLATE OIL, BASE LOAD MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT TABLE A-8-501J

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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 ( o F + 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 NO x COMBUSTOR, DISTILLATE OIL, 75% LOAD

Turbine Inlet Temperature

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Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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/m 3 N) 5555 Turbine Flow (acfm) 2,617,238 2,537,658 2,484,229 2,413,711 (m 3 /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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 3.2 3.1 2.9 2.8 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 2.9 2.8 2.7 2.5 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / lb S (64/32) 2222 HRSG Stack emission rate (lb/hr) 3.2 3.1 2.9 2.8

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 50.4 49.8 49.4 49.0 CT/DB, ppmvd @15% O 2 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% O 2 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)(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 42.0 41.5 41.2 40.8 Basis, ppmvd @ 15% O 2 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% O 2 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)(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 12.0 11.9 11.8 11.7 Basis, ppmvd @ 15% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 3.2 3.1 2.9 2.8
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversion ) 2.9 2.8 2.7 2.5
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x COMBUSTOR, DISTILLATE OIL, 75% LOAD

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Paramete r 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 ( o F + 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 NO x COMBUSTOR, DISTILLATE OIL, 50% LOAD

Turbine Inlet Temperature

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Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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/m 3 N) 5555 Turbine Flow (acfm) 2,331,114 2,266,526 2,223,391 2,162,555 (m 3 /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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 2.8 2.7 2.6 2.5 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 2.5 2.4 2.3 2.2 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / lb S (64/32) 2222 HRSG Stack emission rate (lb/hr) 2.8 2.7 2.6 2.5

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 51.2 50.5 50.2 49.7 CT/DB, ppmvd @15% O 2 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% O 2 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)(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 42.6 42.1 41.8 41.4 Basis, ppmvd @ 15% O 2 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% O 2 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)(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 12.2 12.0 11.9 11.8 Basis, ppmvd @ 15% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 2.8 2.7 2.6 2.5
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversion ) 2.5 2.4 2.3 2.2
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x COMBUSTOR, DISTILLATE OIL, 50% LOAD

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Emission Rate (lb/hr) Parameter firing Natural Gas Maximum Annual
- Base Load a Emission (TPY) b Ambient Temperature ( o F): 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 SO 2 to SO 3 in gas turbine 1,3-Butadiene (a) 0.43 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Acetaldehyde 40 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Acrolein 6.4 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Benzene 12 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Ethylbenzene 32 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Formaldehyde 0.091 ppmvd @15% O 2 (see Table 9a) Naphthalene 1.3 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Polycyclic Aromatic Hydrocarbons (PAH) 2.2 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Propylene Oxide (a) 29 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Toluene 33 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000. Database Xylene 64 lb/10 12 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A13 HAPJanuary 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Formaldehyde (CH 2 O) MW = 30

CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) 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 - O 2 dry)/(20.9 - 15)] x (1- Moisture(%)/100) Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)] Basis, ppm actual- calculated 0.121 0.121 0.121 0.119 CT, ppmvd @15% O 2 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/10 12 Btu) (HHV) 208.9 209.0 209.5 208.2

Note: ppmvd= parts per million, volume dry; O 2 = 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A13a HAPJanuary 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 SO 2 to SO 3 in gas turbine 1,3-Butadiene (a) 16 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Acetaldehyde 0.0 Acrolein 0.0
Benzene 55 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Ethylbenzene 0.0 Formaldehyde 0.091 ppmvd @15% O2 (see Table 10a) Naphthalene 35 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Polycyclic Aromatic Hydrocarbons (PAH) 40 lb/10 12 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/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Beryllium (a) 0.31 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000
Cadmium 4.8 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000
Chromium 11 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000

Lead 14 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Manganese 790 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Mercury 1.2 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Nickel (a) 4.6 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Selenium (a) 25 lb/10 12 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A14 HAPJanuary 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Formaldehyde (CH 2 O) MW = 30

CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 46 (mole. wgt NO x ) 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 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100] Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)] Basis, ppmvw - calculated 0.110 0.108 0.107 0.106 CT, ppmvd @15% O 2 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/10 12 Btu) (HHV) 224.6 223.9 224.3 223.0

Note: ppmvd = parts per million, volume dry; O 2 = oxygen.
Source: MPS, 2011; CT Performance Data; Golder, 2011. TABLE A-14a-501G

CT Only Turbine Inlet Temperature MPS 501J CT, DRY LOW NO x COMBUSTOR, DISTILLATE OIL, BASE LOAD MAXIMUM FORMALDEHYDE EMISSIONS FOR THE PEEC PROJECT

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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 232.0 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/10 12 Btu 4.0 4.64E-07 8.40E-06 Beryllium lb/10 12 Btu 3.0 3.48E-07 6.30E-06
Cadmium lb/10 12 Btu 3.0 3.48E-07 6.30E-06
Chromium lb/10 12 Btu 3.0 3.48E-07 6.30E-06
Lead lb/10 12 Btu 9.0 1.04E-06 1.89E-05 Mercury lb/10 12 Btu 3.0 3.48E-07 6.30E-06 Manganese lb/10 12 Btu 6.0 6.96E-07 1.26E-05
Nickel lb/10 12 Btu 3.0 3.48E-07 6.30E-06
Selenium lb/10 12 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)

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A15 AddUnitsOil-HAPJanuary 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/10 6 scf 2.10E-03 8.93E-05 lb/10 6 scf 2.10E-03 2.05E-04 lb/10 12 Btu 1.20E+01 5.67E-03 Formaldehyde lb/10 6 scf 7.50E-02 3.19E-03 lb/10 6 scf 7.50E-02 7.34E-03 lb/10 12 Btu 7.10E+02 3.36E-01 Naphthalene lb/10 6 scf 6.10E-04 2.59E-05 lb/10 6 scf 6.10E-04 5.97E-05 lb/10 12 Btu 1.30E+00 6.15E-04
Toluene lb/10 6 scf 3.40E-03 1.45E-04 lb/10 6 scf 3.40E-03 3.33E-04 lb/10 12 Btu 3.30E+01 1.56E-02
Dichlorobenzene lb/10 6 scf 1.20E-03 5.10E-05 lb/10 6 scf 1.20E-03 1.17E-04 -- NA NA Acenaphthene lb/10 6 scf 1.80E-06 7.65E-08 lb/10 6 scf 1.80E-06 1.76E-07 -- NA NA Acenaphthylene lb/10 6 scf 1.80E-06 7.65E-08 lb/10 6 scf 1.80E-06 1.76E-07 -- NA NA Acetaldehyde -- NA NA -- NA NA lb/10 12 Btu 4.00E+01 1.89E-02
Acrolein -- NA NA -- NA NA lb/10 12 Btu 6.40E+00 3.03E-03
Anthracene lb/10 6 scf 2.40E-06 1.02E-07 lb/10 6 scf 2.40E-06 2.35E-07 -- NA NA Benzo(a)anthracene lb/10 6 scf 1.80E-06 7.65E-08 lb/10 6 scf 1.80E-06 1.76E-07 -- NA NA

Benzene lb/10 6 scf 2.10E-03 8.93E-05 lb/10 6 scf 2.10E-03 2.05E-04 lb/10 12 Btu 1.20E+01 5.67E-03 Benzo(g,h,i)perylene lb/10 6 scf 1.20E-06 5.10E-08 lb/10 6 scf 1.20E-06 1.17E-07 -- NA NA Chrysene lb/10 6 scf 1.80E-06 7.65E-08 lb/10 6 scf 1.80E-06 1.76E-07 -- NA NA Dibenzo(a,h)anthracene lb/10 6 scf 1.20E-06 5.10E-08 lb/10 6 scf 1.20E-06 1.17E-07 -- NA NA Ethylbenzene -- NA NA -- NA NA lb/10 12 Btu 3.20E+01 1.51E-02
Fluoanthene lb/10 6 scf 3.00E-06 1.28E-07 lb/10 6 scf 3.00E-06 2.93E-07 -- NA NA
Fluorene lb/10 6 scf 2.80E-06 1.19E-07 lb/10 6 scf 2.80E-06 2.74E-07 -- NA NA Indeno(1,2,3-cd)pyrene lb/10 6 scf 1.80E-06 7.65E-08 lb/10 6 scf 1.80E-06 1.76E-07 -- NA NA
Phenanthrene lb/10 6 scf 1.70E-05 7.23E-07 lb/10 6 scf 1.70E-05 1.66E-06 -- NA NA Phenol -- NA NA -- NA NA -- NA NA Pyrene lb/10 6 scf 5.00E-06 2.13E-07 lb/10 6 scf 5.00E-06 4.89E-07 -- NA NA Xylene -- NA NA -- NA NA lb/10 12 Btu 6.40E+01 3.03E-02 1,3-Butadiene -- NA NA -- NA NA lb/10 12 Btu 4.30E-01 2.03E-04 Polycyclic Aromatic Hydrocarbons (PAH) -- NA NA -- NA NA lb/10 12 Btu 2.20E+00 1.04E-03 Propylene Oxide -- NA NA -- NA NA lb/10 12 Btu 2.90E+01 1.37E-02

Arsenic lb/10 6 scf 2.00E-04 8.50E-06 lb/10 6 scf 2.00E-04 1.96E-05 -- NA NA Beryllium lb/10 6 scf 1.20E-05 5.10E-07 lb/10 6 scf 1.20E-05 1.17E-06 -- NA NA
Cadmium lb/10 6 scf 1.10E-03 4.68E-05 lb/10 6 scf 1.10E-03 1.08E-04 -- NA NA
Chromium lb/10 6 scf 1.40E-03 5.95E-05 lb/10 6 scf 1.40E-03 1.37E-04 -- NA NA
Cobalt lb/10 6 scf 8.40E-05 3.57E-06 lb/10 6 scf 8.40E-05 8.22E-06 -- NA NA Mercury lb/10 6 scf 2.60E-04 1.11E-05 lb/10 6 scf 2.60E-04 2.54E-05 -- NA NA Manganese lb/10 6 scf 3.80E-04 1.62E-05 lb/10 6 scf 3.80E-04 3.72E-05 -- NA NA
Nickel lb/10 6 scf 2.10E-03 8.93E-05 lb/10 6 scf 2.10E-03 2.05E-04 -- NA NA
Selenium lb/10 6 scf 2.40E-05 1.02E-06 lb/10 6 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-HAPJanuary 2012113-87618PollutantNatural GasDistillate FuelOilNaturalGasDistillateFuel Oil Natural GasDistillateFuel OilNaturalGasDistillateFuel Oil Natural GasDistillateFuel Oil Natural GasDistillateFuel Oil TotalNatural Gas OnlyCO22,818.7 0.0 116.9 163.0 329,386.2 0.08760 01,442,711.6 0 1,442,711.6 0 1,442,711.6CH42,818.7 0.0 0.002204 0.006612 6.2 0.08760 027.2 0 571.4 0 571.4N2O2,818.7 0.0 0.0002204 0.001322 0.6 0.08760 02.7 0 843.5 0 843.5Total 1,444,126.5 0.0 1,444,126.5Natural Gas & Distillate Fuel OilCO22,818.7 2,333.6 116.9 163.0 329,386.2 380,393.57760 10001,278,018.5 190,196.7 1,278,018.5 190,196.7 1,468,215.2CH42,818.7 2,333.6 0.002204 0.006612 6.2125 15.42977760 100024.1 7.7 506.19 162.01 668.2N2O2,818.7 2,333.6 0.0002204 0.001322 0.6212 3.08597760 10002.4 1.5 747.24 478 1225.6Total 1,279,271.9 190,837.1 1,470,109.0Maximum Total 1,444,126.5 190,837.1 1,470,109.0aTable C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtuPollutant Natural Gas Distillate Fuel OilCO253.02 73.96CH40.001 0.003N2O0.0001 0.0006Conversion factor from kg/MMBtu to lb/MMBtu: 2.204bCH4and N2O are multiplied by CO2e factorPollutant CO2eFactorCH421N2O 310GREENHOUSE GAS (GHG) EMISSIONSMPS 501J CT, DRY LOW NOxCOMBUSTOR, BASE LOADTABLE A-17(TPY)Heat Input at 750F Emission FactoraHourly GHG Emissions(MMBtu/hr) (lb/MMBtu) (lb/hr) Operating Hours (TPY)Annual GHG EmissionsCO2e Emission RatebMaximumY:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Tab A17 CT-GHGJanuary 2012 113-87618

Maximum Emission Hourl y 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)

CO 2 99.77 116.9 11,658.7 2,000 11,658.7 11,658.7 CH 4 99.77 0.002204 0.220 2,000 0.220 4.618 N 2 O 99.77 0.0002204 0.0220 2,000 0.022 6.817 11,670.2 Emergency Generator (Fuel Oil)

CO 2 21.01 163.0 3,424.8 200 342.5 342.5 CH 4 21.01 0.006612 0.139 200 0.014 0.29 N 2 O 21.01 0.001322 0.028 200 0.0028 0.86 343.6 Natural Gas Heater (Natural Gas)
CO 2 9.90 116.9 1,156.9 8,760 5,067.1 5067.1 CH 4 9.90 0.002204 0.022 8,760 0.096 2.01 N 2 O 9.90 0.0002204 0.0022 8,760 0.0096 2.96 5,072.1 Fire Pump Engine (Fuel Oil)

CO 2 2.32 163.0 378.2 80 15.1 15.1 CH 4 2.32 0.006612 0.0153 80 0.00061 0.01 N 2 O 2.32 0.001322 0.0031 80 0.00012 0.04 15.2 Gas Compressor (Natural Gas)

CO 2 53.98 116.9 6,308.1 8,760 27,629.5 27,629.5 CH 4 53.98 0.002204 0.119 8,760 0.521 10.94 N 2 O 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 CO 2 53.02 73.96 CH 4 0.001 0.003 N 2 O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH 4 and N 2 O are multiplied by CO 2 e factor

Pollutant CO 2e Factor CH 4 21
N 2 O 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

## A TTACHMENTTANKS 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) 

### Page 1 TANKS 4.0 Report

1/13/2012 file://C:\AIRPROG\Tanks409d\summarydisplay.htm165,000 BBL - No. 2 Fuel Oil; PEEC - Vertical Fixed Roof Tank West Palm Beach, Florida T ANKS 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 

### Page 2 TANKS 4.0 Report

1/13/2012 file://C:\AIRPROG\Tanks409d\summarydisplay.htmEmissions Report for: Annual

165,000 BBL - No. 2 Fuel Oil; PEEC - Vertical Fixed Roof Tank West Palm Beach, Florida T ANKS 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 

### Page 3 TANKS 4.0 Report

1/13/2012 file://C:\AIRPROG\Tanks409d\summarydisplay.htm

## APPENDIX BJanuary 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 ( o F + 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/ft 3 ) 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 NO x COMBUSTOR, NATURAL GAS, BASE LOAD

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CT Only

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 1 0 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 SO 2 emission rate (lb/hr) 15.6 14.9 14.3 13.7 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0
DB SO 2 emission rate (lb/hr) -- -- -- -- Conversion (%) from SO 2 to SO 3 in DB -- -- -- -- Remaining SO 2 (lb/hr) after conversion 14.0 13.4 12.8 12.3 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 15.6 14.9 14.3 13.7
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0 0 0 0
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 (lb/hr)(remaining SO 2 after conversion) 14.0 13.4 12.8 12.3
SCR Conversion to H 2 SO 4 (% 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; O 2 = 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 NO x 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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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 ( o F + 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/ft 3 ) 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

N ote: 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 NO x COMBUSTOR, NATURAL GAS, 80% LOAD DESIGN INFORMATION AND STACK PARAMETERS FOR THE PEEC PROJECT TABLE B-3-SH

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B3-G80January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 12.9 12.0 11.6 10.9 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 11.6 10.8 10.4 9.8 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 12.9 12.0 11.6 10.9
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 00 0 0
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after co n 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 NO x 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-G80January 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 ( o F + 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/ft 3 ) 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 NO x 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-G60January 2012 113-87618

Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 [(NH 4 ) 2 SO 4 ] from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 10.5 9.9 9.5 9.0 Conversion (%) from SO 2 to SO 3 in CT 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 9.4 8.9 8.6 8.1 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 /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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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% O 2 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)= SO 2 emission (lb/hr) x Conversion to H 2 SO 4 (% by weight)/100
CT SO 2 emission rate (lb/hr) 10.5 9.9 9.5 9.0
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 00 0 0
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after co n 9.4 8.9 8.6 8.1
SCR Conversion to H 2 SO 4 (% 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 NO x 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-G60January 2012 113-87618

Paramete r 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 ( o F + 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 NO x 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-O100January 2012 113-87618

Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 4.1 3.9 3.8 3.6 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 3.7 3.5 3.4 3.2 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / lb S (64/32) 2222 HRSG Stack emission rate (lb/hr) 4.1 3.9 3.8 3.6

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 54.5 53.7 52.9 51.9 CT/DB, ppmvd @15% O 2 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% O 2 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)(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 13.0 12.8 12.6 12.4 Basis, ppmvd @ 15% O 2 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% O 2 10 10 10 10 HRSG Stack emission rate (lb/hr) (maximum) 68.0 64.0 62.0 59.0

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 60 min/hr Basis, ppm actual 1.3 1.3 1.3 1.2 Basis, ppmvd @ 15% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 4.1 3.9 3.8 3.6
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversio n 3.7 3.5 3.4 3.2
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x COMBUSTOR, DISTILLATE OIL, BASE LOAD MAXIMUM EMISSIONS FOR CRITERIA POLLUTANTS FOR THE PEEC PROJECT TABLE B-8-SH

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B8-O100January 2012 113-87618

Paramete r 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 ( o F + 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 NO x 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-O80January 2012 113-87618

Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 3.4 3.2 3.1 2.9 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 3.1 2.9 2.8 2.6 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / lb S (64/32) 2222 HRSG Stack emission rate (lb/hr) 3.4 3.2 3.1 2.9

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 60 min/hr Basis, ppm actual 56.1 54.6 53.4 51.9 CT/DB, ppmvd @15% O 2 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% O 2 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)(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 13.3 13.0 12.7 12.4 Basis, ppmvd @ 15% O 2 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% O 2 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)(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 1.3 1.3 1.3 1.2 Basis, ppmvd @ 15% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 3.4 3.2 3.1 2.9
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversion ) 3.1 2.9 2.8 2.6
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x 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 B10-080January 2012 113-87618

Paramete r 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 ( o F + 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 NO x COMBUSTOR, DISTILLATE OIL, 70% LOAD

Turbine Inlet Temperature

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Turbine Inlet Temperature Parameter 35 °F 59 °F 75 °F 95 °F

Particulate (including PM 2.5 ) from CT and SCR
Total PM 10 = PM 10 (front half) + PM 10 [(NH 4 ) 2 SO 4 ] in HRSG only (back-half)
a. PM 10 (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. PM 10 ((NH 4 ) 2 SO 4 ) from HRSG only (back half) = Sulfur trioxide from conversion of SO 2 converts to ammonium sulfate (= PM 10 ) 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 SO 2 emission rate (lb/hr) 3.1 2.9 2.8 2.7 Conversion (%) from SO 2 to SO 3 10.0 10.0 10.0 10.0 Remaining SO 2 (lb/hr) in CT after conversion 2.8 2.7 2.5 2.4 Conversion (%) from SO 2 to SO 3 in SCR 3.0 3.0 3.0 3.0
MW SO 3 / SO 2 (80/64) 1.3 1.3 1.3 1.3 Conversion (%) from SO 3 to (NH 4 ) 2 (SO 4 ) 100 100 100 100 MW (NH 4 ) 2 SO 4 / SO 3 (132/80) 1.7 1.7 1.7 1.7 HRSG Particulate as (NH 4 ) 2 (SO 4 ) (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 SO 2 / lb S (64/32) 2222 HRSG Stack emission rate (lb/hr) 3.1 2.9 2.8 2.7

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 56.5 54.9 53.6 51.8 CT/DB, ppmvd @15% O 2 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% O 2 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)(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 13.5 13.1 12.8 12.3 Basis, ppmvd @ 15% O 2 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% O 2 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)(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 1.3 1.3 1.3 1.2 Basis, ppmvd @ 15% O 2 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% O 2 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 SO 2 emission rate (lb/hr) 3.1 2.9 2.8 2.7
CT Conversion to H 2 SO 4 (% by weight) 10 10 10 10
DB SO 2 emission rate (lb/hr) 0000
DB Conversion to H 2 SO 4 (%) 20 20 20 20
SCR SO 2 emission rate (lb/hr) - calculated (remaining SO 2 after conversion ) 2.8 2.7 2.5 2.4
SCR Conversion to H 2 SO 4 (% 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/10 12 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 NO x COMBUSTOR, DISTILLATE OIL, 70% LOAD

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Parameter 35 °F 59 °F 75 °F 95 °F

Formaldehyde (CH 2 O)

CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 30 (mole. wgt CH 2 O) x 2116.8 lb/ft 2 (pressure) / [1545.7 (gas constant, R) x Actual Tem p. (°R)] x 60 min/hr
CH 2 O (ppm actual) = CH 2 O (ppmd @ 15%O 2 ) x [(20.9 - O 2 dry)/(20.9 - 15)] x (1- Moisture(%)/100) Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)] Basis, ppm actual- calculated 0.116 0.115 0.139 0.111 CT, ppmvd @15% O 2 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/10 12 Btu) (HHV) 226.2 224.3 282.0 219.1

Note: ppmvd= parts per million, volume dry; O 2 = 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 ( o F): 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 SO 2 to SO 3 in gas turbine 1,3-Butadiene (a) 0.43 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Acetaldehyde 40 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Acrolein 6.4 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Benzene 12 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Ethylbenzene 32 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Formaldehyde 0.091 ppmvd @15% O 2 (see Table 9a) Naphthalene 1.3 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Polycyclic Aromatic Hydrocarbons (PAH) 2.2 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000 Propylene Oxide (a) 29 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000

Toluene 33 lb/10 12 Btu; AP-42,Table 3.1-3. EPA 2000. Database Xylene 64 lb/10 12 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 (CH 2 O)

CH 2 O (lb/hr) = CH 2 O (ppm actual) x Volume flow (acfm) x 30 (mole. wgt CH 2 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 - O 2 dry)/(20.9 - 15)] x [1- Moisture(%)/100] Oxygen (%, dry)(O 2 dry) = Oxygen (%)/[1-Moisure (%)] Basis, ppmvw - calculated 0.118 0.116 0.115 0.112 CT, ppmvd @15% O 2 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/10 12 Btu) (HHV) 238.8 236.0 234.3 225.6

Note: ppmvd= parts per million, volume dry; O 2 = oxygen.
Source: Siemens, 2011; CT Performance Data; Golder, 2011. TABLE B-14a-SH

CT Only Turbine Inlet Temperature SIEMENS H CT, DRY LOW NO x 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 SO 2 to SO 3 in gas turbine 1,3-Butadiene (a) 16 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Acetaldehyde 0.0 Acrolein 0.0
Benzene 55 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Ethylbenzene 0.0 Formaldehyde 0.091 ppmvd @15% O2 (see Table 10a) Naphthalene 35 lb/10 12 Btu; AP-42,Table 3.1-4. EPA 2000 Polycyclic Aromatic Hydrocarbons (PAH) 40 lb/10 12 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/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Beryllium (a) 0.31 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000

Cadmium 4.8 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000

Chromium 11 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000

Lead 14 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Manganese 790 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Mercury 1.2 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Nickel (a) 4.6 lb/10 12 Btu; AP-42,Table 3.1-5. EPA 2000 Selenium (a) 25 lb/10 12 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/10 12 Btu 4.0 4.65E-07 8.40E-06 Beryllium lb/10 12 Btu 3.0 3.49E-07 6.30E-06
Cadmium lb/10 12 Btu 3.0 3.49E-07 6.30E-06
Chromium lb/10 12 Btu 3.0 3.49E-07 6.30E-06
Lead lb/10 12 Btu 9.0 1.05E-06 1.89E-05 Mercury lb/10 12 Btu 3.0 3.49E-07 6.30E-06 Manganese lb/10 12 Btu 6.0 6.97E-07 1.26E-05
Nickel lb/10 12 Btu 3.0 3.49E-07 6.30E-06
Selenium lb/10 12 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/10 6 scf 2.10E-03 8.93E-05 lb/10 12 Btu 1.20E+01 5.67E-03 Formaldehyde lb/10 6 scf 7.50E-02 3.19E-03 lb/10 12 Btu 7.10E+02 3.36E-01 Naphthalene lb/10 6 scf 6.10E-04 2.59E-05 lb/10 12 Btu 1.30E+00 6.15E-04
Toluene lb/10 6 scf 3.40E-03 1.45E-04 lb/10 12 Btu 3.30E+01 1.56E-02
Dichlorobenzene lb/10 6 scf 1.20E-03 5.10E-05 -- NA NA Acenaphthene lb/10 6 scf 1.80E-06 7.65E-08 -- NA NA Acenaphthylene lb/10 6 scf 1.80E-06 7.65E-08 -- NA NA Acetaldehyde -- NA NA lb/10 12 Btu 4.00E+01 1.89E-02
Acrolein -- NA NA lb/10 12 Btu 6.40E+00 3.03E-03
Anthracene lb/10 6 scf 2.40E-06 1.02E-07 -- NA NA Benzo(a)anthracene lb/10 6 scf 1.80E-06 7.65E-08 -- NA NA

Benzene lb/10 6 scf 2.10E-03 8.93E-05 lb/10 12 Btu 1.20E+01 5.67E-03 Benzo(g,h,i)perylene lb/10 6 scf 1.20E-06 5.10E-08 -- NA NA Chrysene lb/10 6 scf 1.80E-06 7.65E-08 -- NA NA Dibenzo(a,h)anthracene lb/10 6 scf 1.20E-06 5.10E-08 -- NA NA Ethylbenzene -- NA NA lb/10 12 Btu 3.20E+01 1.51E-02
Fluoanthene lb/10 6 scf 3.00E-06 1.28E-07 -- NA NA
Fluorene lb/10 6 scf 2.80E-06 1.19E-07 -- NA NA Indeno(1,2,3-cd)pyrene lb/10 6 scf 1.80E-06 7.65E-08 -- NA NA
Phenanthrene lb/10 6 scf 1.70E-05 7.23E-07 -- NA NA Phenol -- NA NA -- NA NA Pyrene lb/10 6 scf 5.00E-06 2.13E-07 -- NA NA Xylene -- NA NA lb/10 12 Btu 6.40E+01 3.03E-02 1,3-Butadiene -- NA NA lb/10 12 Btu 4.30E-01 2.03E-04 Polycyclic Aromatic Hydrocarbons (PAH) -- NA NA lb/10 12 Btu 2.20E+00 1.04E-03 Propylene Oxide -- NA NA lb/10 12 Btu 2.90E+01 1.37E-02

Arsenic lb/10 6 scf 2.00E-04 8.50E-06 -- NA NA Beryllium lb/10 6 scf 1.20E-05 5.10E-07 -- NA NA
Cadmium lb/10 6 scf 1.10E-03 4.68E-05 -- NA NA
Chromium lb/10 6 scf 1.40E-03 5.95E-05 -- NA NA
Cobalt lb/10 6 scf 8.40E-05 3.57E-06 -- NA NA Mercury lb/10 6 scf 2.60E-04 1.11E-05 -- NA NA Manganese lb/10 6 scf 3.80E-04 1.62E-05 -- NA NA
Nickel lb/10 6 scf 2.10E-03 8.93E-05 -- NA NA
Selenium lb/10 6 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

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B16 AddUnitsGas-HAPJanuary 2012113-87618PollutantNatural GasDistillate FuelOil Natural GasDistillateFuel Oil Natural GasDistillateFuel OilNaturalGasDistillateFuel Oil Natural GasDistillateFuel Oil Natural GasDistillateFuel Oil TotalNatural Gas OnlyCO22,539.0 0.0 116.9 163.0 296,697.6 0.08760 01,299,535.4 0 1,299,535.4 0 1,299,535.4CH42,539.0 0.0 0.002204 0.006612 5.6 0.08760 024.5 0 514.7 0 514.7N2O2,539.0 0.0 0.0002204 0.001322 0.6 0.08760 02.5 0 759.8 0 759.8Total 1,300,810.0 0.0 1,300,810.0Natural Gas & Distillate Fuel OilCO22,539.0 2,453.0 116.9 163.0 296,697.6 399,858.27760 10001,151,186.6 199,929.1 1,151,186.6 199,929.1 1,351,115.8CH42,539.0 2,453.0 0.002204 0.006612 5.5960 16.21927760 100021.7 8.1 455.96 170.30 626.3N2O2,539.0 2,453.0 0.0002204 0.001322 0.5596 3.24387760 10002.2 1.6 673.08 503 1175.9Total 1,152,315.7 200,602.2 1,352,917.9Maximum Total 1,300,810.0 200,602.2 1,352,917.9aTable C-2, Subpart C, 40 CFR 98. Emission factors in kg/MMBtuPollutantNatural Gas Distillate Fuel OilCO253.02 73.96CH40.001 0.003N2O0.0001 0.0006Conversion factor from kg/MMBtu to lb/MMBtu: 2.204bCH4and N2O are multiplied by CO2e factorPollutant CO2eFactorCH421N2O 310TABLE B-17SIEMENS H CT, DRY LOW NOx COMBUSTOR, BASE LOADMaximumGREENHOUSE GAS (GHG) EMISSIONS(TPY)Heat Input at 750F Emission FactoraHourly GHG Emissions Annual GHG EmissionsCO2e Emission Rateb(MMBtu/hr) (lb/MMBtu) (lb/hr) Operating Hours (TPY)Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B17 CT-GHGJanuary 2012 113-87618

Maximum Emission Hourl y Annual CO 2 e 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)

CO 2 21.01 163.0 3,424.8 200 342.5 342.5 CH 4 21.01 0.006612 0.139 200 0.014 0.29 N 2 O 21.01 0.001322 0.028 200 0.0028 0.86 343.6 Natural Gas Heater (Natural Gas)
CO 2 9.90 116.9 1,156.9 8,760 5,067.1 5067.1 CH 4 9.90 0.002204 0.022 8,760 0.096 2.01 N 2 O 9.90 0.0002204 0.0022 8,760 0.0096 2.96 5,072.1 Fire Pump Engine (Fuel Oil)

CO 2 2.32 163.0 378.8 80 15.2 15.2 CH 4 2.32 0.006612 0.0154 80 0.00061 0.01 N 2 O 2.32 0.001322 0.0031 80 0.00012 0.04 15.2 Gas Compressor (Natural Gas)

CO 2 53.98 116.9 6,308.1 8,760 27,629.5 27,629.5 CH 4 53.98 0.002204 0.119 8,760 0.521 10.94 N 2 O 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 CO 2 53.02 73.96 CH 4 0.001 0.003 N 2 O 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

b CH 4 and N 2 O are multiplied by CO 2 e factor

Pollutant CO 2e Factor CH 4 21
N 2 O 310 TABLE B-18 GREENHOUSE GAS (GHG) EMISSIONS FOR ADDITIONAL PEEC EMISSION UNITS

Y:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\SiemensH_B_PEEC 75 deg_12JAN2012rev1.xlsx:Tab B18 Other-GHG

## APPENDIX CJanuary 2012 113-87618

Maximum

2-Year 2006 2007 2008 2009 Average Pollutant Unit 2006 2007 2008 2009 2010 2007 2008 2009 2010 (tons/year)

SO 2 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

PM 10 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

NO x 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 SO 2 emissions and based on ratio of AP-42 emission factors for fuel oil combustion (Table 1.3-1) for SO 3 and SO 2 . SO 3 is assumed to be converted to H 2 SO 4 .

SO 3 emission factor 5.7 S lb/1000 gal (S = sulfur content)
SO 2 emission factor 157 S lb/1000 gal (S = sulfur content)
Ratio SO 3 /SO 2 emissions 0.036 fraction
SO 3 molecular wgt (MW) 80
H 2 SO 4 MW 98
Ratio H 2 SO 4 /SO 2 MW 1.225
Ratio H 2 SO 4 /SO 2 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 AORsummaryJanuary 2012113-87618Unit IDOperatingYearOperation Time(hrs)MonthsReportedGross Load(MWh)CO2Emissions(TPY)HeatInput(mmBtu) Primary Fuel Secondary FuelMaximum Heatinput capacity(MMBtu/hr)Unit 1 2010 58.59 12 8,068.30 7,269.89 81,243.34 Residual Oil Pipeline Natural Gas 2475Unit 2 2010 78.96 12 11,418.42 9,685.68 110,216.93 Residual Oil Pipeline Natural Gas 2475Unit 3 2010 5,646.15 12 816,717.75 651,953.52 8,671,770.00 Residual Oil Pipeline Natural Gas 4180Unit 4 2010 4,863.70 12 703,514.81 592,940.71 7,620,377.43 Residual Oil Pipeline Natural Gas 4180Unit 1 2009 2,352.73 12 218,983.50 176,410.18 2,311,759.73 Residual Oil Pipeline Natural Gas 2475Unit 2 2009 2,581.57 12 253,878.27 200,338.53 2,657,008.68 Residual Oil Pipeline Natural Gas 2475Unit 3 2009 5,992.95 12 936,274.52 766,171.73 10,191,575.58 Residual Oil Pipeline Natural Gas 4180Unit 4 2009 6,051.82 12 915,856.15 748,031.50 9,901,521.02 Residual Oil Pipeline Natural Gas 4180Unit 1 2008 912.91 5 76,175.22 62,258.08 822,342.76 Residual Oil Pipeline Natural Gas 2400Unit 2 2008 1,384.32 5 129,071.73 108,435.70 1,387,612.06 Residual Oil Pipeline Natural Gas 2400Unit 3 2008 3,132.55 5 534,797.16 415,737.09 5,537,674.70 Residual Oil Pipeline Natural Gas 4180Unit 4 2008 3,245.35 5 605,729.60 468,171.89 6,208,456.77 Residual Oil Pipeline Natural Gas 4180Unit 1 2007 3,128.77 12 318,360.20 288,111.64 3,393,060.91 Residual Oil Pipeline Natural Gas 2400Unit 2 2007 2,607.50 12 257,766.53 233,711.48 2,744,636.30 Residual Oil Pipeline Natural Gas 2400Unit 3 2007 5,573.87 12 1,086,955.26 859,762.61 10,941,432.19 Residual Oil Pipeline Natural Gas 4180Unit 4 2007 6,414.33 12 1,297,789.65 1,040,523.23 12,857,134.88 Residual Oil Pipeline Natural Gas 4180Unit 1 2006 3,792.97 12 468,698.42 371,454.59 4,777,247.08 Residual Oil Pipeline Natural Gas 2400Unit 2 2006 3,826.16 12 464,109.13 370,538.89 4,784,052.94 Residual Oil Pipeline Natural Gas 2400Unit 3 2006 7,130.62 12 1,393,401.45 1,113,274.71 14,310,310.05 Residual Oil Pipeline Natural Gas 4180Unit 4 2006 5,234.70 12 1,033,553.37 812,679.47 10,593,474.53 Residual Oil Pipeline Natural Gas 4180SUMMARY OF CO2EMISSIONS FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANTTABLE C-2BASED ON ACID RAIN PROGRAM DATAY:\Projects\2011\113-87618 FPL PEEC SCA\SCA+PSD common tables\MHI501J_A_PEEC 75 deg_12JAN2011.xlsx:Table C-2 PPE CO2acidrainJanuary 2012 113-87618

Actual
Annual Emission CO 2 e c Emission CO 2 e 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 CH 4 0.003 0.001 0.003
N 2 O 0.0006 0.0001 0.0006

Conversion factor from kg/MMBtu to lb/MMBtu: 2.204

c N 2 O and CH 4 emissions are multiplied by CO 2 e factor Pollutant CO 2e Factor
N 2 O 310
CH 4 21 Total Heat Input (MMBtu) TABLE C-3 ESTIMATED ANNUAL EMISSIONS OF N 2 O AND CH 4 FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT USING AOR DATA

N 2 O Emissions CH 4 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&CH4January 2012113-87618Maximum2-Year2006 2007 2008 2009 AveragePollutant Unit 2006 2007 2008 2009 2010 2007 2008 2009 2010 (TPY)CO2a1 371,454.6 288,111.6 62,258.1 176,410.2 7,269.9 329,783.1 175,184.9 119,334.1 91,840.02 370,538.9 233,711.5 108,435.7 200,338.5 9,685.7 302,125.2 171,073.6 154,387.1 105,012.13 1,113,274.7 859,762.6 415,737.1 766,171.7 651,953.5 986,518.7 637,749.9 590,954.4 709,062.64 812,679.5 1,040,523.2 468,171.9 748,031.5 592,940.7 926,601.3 754,347.6 608,101.7 670,486.12,667,947.7 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 1,576,400.9 2,545,028.3N2Ob4,257.4 4,485.4 2,759.4 2,604.8 1,837.1 4,371.4 3,622.4 2,682.1 2,220.9 4,371.4CH4b1,638.2 1,637.7 1,141.0 1,052.9 731.6 1,638.0 1,389.4 1,097.0 892.3 1,638.0TOTAL 2,551,037.7aAnnual Emissions based on CEMS data obtained from EPA Acid Rain database.bN2O and CH4emissions based on actual annual heat input from Annual Operating ReportsSource: FPL, 2011TABLE C-4SUMMARY OF MAXIMUM ANNUAL GHG EMISSIONS FOR THE EXISTING UNITS 1 THROUGH 4 AT PORT EVERGLADES PLANT2-Year AverageAnnual CO2e Emissions (TPY)Annual CO2Equivalent 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.

Y:\Projects\2011\113-87618 FPL PEEC SCA\Appx (10.1-10.11)\A ppx 10.2.5 AC Pmt (PSD)\Figures\Appendix D-1.docx

### 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)\A ppx 10.2.5 AC Pmt (PSD)\Figures\Appendix D-2.docx

## APPENDIX ECO 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 58 7349.178 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 P OINT 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 G C5075 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 SRC PARAM 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 G A7575 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 35 9.3 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 G A1035

- 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 BUILDLE N GA1035

- GA7595 30.42 32.49 33.57 33.63 32.66 31.59SO 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 YBAD J 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

- GB759 5 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

- GB 7595 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 2 3.77 SO BUILDWID GC1035

- GC7595 19.06 23.60 27.42 30.41 32.48 33.56SO 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 G C1035

- 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_APUAIRDATA 92803 2006 Miami_

- _FL_Intl_Univ

PROFBASE 11 FEET STARTEND 06 01 01 06 1 2 31 ME FINISHED

**

**************************************** ** AERMOD Output Pathway

****************************************

**

** OU STARTING RECTABLE ALLAVE FIRST OU FINISHEDAERBOB 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 YEA R 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 58660 0. 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. 2 885300. 06100312

07 9.13692 586300. 2884800. 07103021 08 8.20163 586100. 2885600. 08090906 09 8.29798 586700. 2885600. 090816 12 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 10123124HIGH 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 7.5182 0 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. 28 84900. 07103018 08 8.47975 588100. 2885600. 08051211 09 8.49000 586800. 2885600. 09081610 10 8.04296 586700. 2885400. 1007171 2 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 288590 0.0 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 7.7 6518 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. 0908161010 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. 288540 0. 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 10.37 696 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. 0710302108 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. 0 6110404

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 0712 3124 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 5 86200. 2885600. 08090906 09 9.24235 586700. 2885600. 09081612 10 9.24673 586700. 2885600. 10072012 HIGH 1

- Hour 06 10.60278 58650 0. 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 1 0123124 HIGH 24

- Hour 06 6.88299 586500. 2885000. 06110424

07 8.65473 586600. 2885000. 07103024 08 7.54516 586700. 2885600. 08090 924 09 7.12005 586400. 2885400. 09110824 10 5.07750 586800. 2885500. 10051224 HIGH 8

- Hour06 11.02324 586800. 2885200. 06101516 07 12.31041 586500. 2884900. 07103024 08 11.70751 586800. 2885600. 08090916 09 11.08582 586800. 2885400. 09110816 1 0 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 58 6800. 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. 2 885200. 06101516

07 12.20136 586500. 2884900. 07103024 08 11.55586 586800. 2885600. 08090916 09 10.93816 586800. 2885700. 091109 16 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 0912312410 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 10.6018 1 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. 28 84900. 07103021 08 12.10100 586300. 2885600. 08090906 09 11.25941 586800. 2885600. 09081612 10 11.36777 586800. 2885500. 1005121 5 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 0.0 0 0.00 DISCRETE 0.00 0.00CO 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 58 7349.178 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 P OINT 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 O C5075 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 SRC PARAM 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 O A7575 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 45 2.0 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 O A1035

- 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 BUILDLE N OA1035

- OA7595 30.42 32.49 33.57 33.63 32.66 31.59SO 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 YBAD J 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

- OB759 5 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

- OB 7595 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 2 3.77 SO BUILDWID OC1035

- OC7595 19.06 23.60 27.42 30.41 32.48 33.56SO 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 O C1035

- 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_APUAIRDATA 92803 2006 Miami_

- _FL_Intl_Univ

PROFBASE 11 FEET STARTEND 06 01 01 06 1 2 31 ME FINISHED

**

**************************************** ** AERMOD Output Pathway

****************************************

**

** OU STARTING RECTABLE ALLAVE FIRST OU FINISHEDAERBOB 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 YEA R 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 58650 0. 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. 2 885300. 06100312

07 4.52250 586600. 2885300. 07100615 08 4.80044 586600. 2885800. 08083115 09 4.99484 586700. 2885400. 090426 12 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 10123124HIGH 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 4.2856 9 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. 28 85300. 07052511 08 4.88367 588100. 2885600. 08051212 09 5.09399 588200. 2885700. 09030114 10 4.85012 586700. 2885600. 1007201 2 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 288590 0.0 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 4.4 7909 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. 0903011410 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. 288540 0. 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 5.83 755 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. 0710302108 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. 0 6110404

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 0712 3124 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 5 86600. 2885800. 08083115 09 5.28175 586700. 2885600. 09081612 10 5.18143 586700. 2885600. 10072012 HIGH 1

- Hour 06 5.32407 58670 0. 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 1 0123124 HIGH 24

- Hour 06 2.79975 586500. 2885000. 06110424

07 3.80206 586500. 2884900. 07103024 08 3.12445 586300. 2885700. 08090 924 09 2.71128 586700. 2885400. 09042624 10 2.46868 586600. 2885300. 10062424 HIGH 8

- Hour06 5.64548 586700. 2885100. 06110416 07 6.19603 586300. 2884800. 07103024 08 5.94213 586700. 2885100. 08101416 09 6.18741 586700. 2885400. 09042616 1 0 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 58 8000. 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. 2 885100. 06110416

07 5.84593 586300. 2884800. 07103024 08 5.68602 586700. 2885100. 08101416 09 5.93089 586700. 2885400. 090426 16 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 0912312410 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 4.8955 4 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. 28 84700. 07103021 08 5.63173 586700. 2885500. 08083015 09 5.97416 586700. 2885600. 09081612 10 5.90002 586700. 2885600. 1007201 2 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 0.0 0 0.00 DISCRETE 0.00 0.00CO 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 POIN T 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 POIN T 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 GA1 035

- 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 27.43SO 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 B UILDWID 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

- GB75 95 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 S O 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

- G B7595 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 13.94SO BUILDWID GC1 035

- 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 BUILD WID 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 COMP RS1 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

- 12 3.23 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 0.00SO 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 BUI LDHGT 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 B UILDLEN 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 COMPRS 3 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 0.00SO 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 COMP RS3 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 BUILDLE N 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 FINISHEDAERBOB 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 58690 0.0 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 0.00CO 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 OA 1035

- 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 2 3.77 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 31.5 9 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 27.43SO 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

- 36.2 7

- 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 23.7 7 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

- OB7 595 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 1 7.07 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 39.0 1 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 13.94SO BUILDWID OC 1035

- 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 3 3.16 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 33.2 5 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 2 0.42 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 BUIL DWID 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 COM PRS1 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

- 1 23.23 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 0.00SO 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 BU ILDHGT 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 0.0 0 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 31.7 7 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 S O 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 COMPR S3 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 0.00SO 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 COM PRS3 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 0.0 0 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 BUILDL EN 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 YBAD J 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.rouRE 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 FINISHEDAERBOB 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
AE RMOD 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 CO NC 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

0 7 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 0.00CO 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 58744 3.291 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 BUILDHG T 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 BUIL DLEN 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 27.43SO 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 Y BADJ 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

- OB 7595 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 OB1 035

- 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 13.94SO BUILDWI D 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 XBAD J 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 0.0 0 **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 0.0 0 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 0.0 0 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 0.0 0 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 0.0 0 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 0.00SO 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 S O 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 0.0 0 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 0.0 0 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 COM PRS3 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 C OMPRS3 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 0.0 0 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 0.0 0 0.00 0.00 0.00 0.00SO 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 BUIL DWID 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 BU ILDLEN 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 0.0 0 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 0.0 0 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 FINISH ED

**

**************************************** ** 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 FINISHEDAERBOB 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 58680 0.0 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 0.00CO 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 58727 9.960 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 C OMPRS3 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 3 3.71 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 BU ILDWID 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

- OA759 5 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 27.43SO 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

- OA 7595 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 2 3.77 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 33.5 6 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 OB10 35

- 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 3 5.54 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 O B1035

- 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 23.7 7 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 BUILD WID 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 13.94SO 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 2 9.32 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 XB ADJ 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

- OC759 5

- 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 Y BADJ 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 0.00SO 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 COMPRS 2 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 COMP RS2 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 CO MPRS2 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 BUILD WID 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 XBA DJ 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 0.00SO 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 Y BADJ 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 *** 18:01:4 5 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 ( 58 6600.00, 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 = GRID POLR DC = DISCCART DP = DISCPOLR*** AERMOD

- VERSION 11103 *** *** FPL FUTURE CO AAQS WITH MHI "J" CLASS GAS 9/16/11 *** 10/05/11 *** FT. LAU DERDALE/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

- I D

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

CTS HIGH 2ND HIGH VALUE IS 35.60065 ON 09051613: AT ( 586600.00, 2885600.00, 3.00, 3.00, 0.0 0) 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, 0.0 0) 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 E rror 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 Ide ntified ( 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 Parame ters ** 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 0.0 0 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 23.7 7 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 AUXBL R 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

- 4.39SO SRCGROUP ALL

SO FINISHED

**

****************************************

* * ISCST3 Receptor Pathway

****************************************

**

** RE STARTING INCLUDED PEM1.rou RE FINISHED

**

**************************************** ** AERMOD Meteorology Pathway

****************************************

**

** ME S TARTING 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 FINISHEDAERBOB 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. LAUDE RDALE/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 5876 88. 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. 0 8112503 09 358.88657 587688. 2885128. 09011003 10 392.66406 587641. 2885127. 10121603 HIGH 1

- Hour 06 538.81488 587264. 2885112. 06100 623

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 0.00S:\Projects\FPL\Port Everglades Modernization Sept1 1\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 6.7 1 SRCPARAM GB1035 2.14 45.4 364.3 18.61 6.7 1 SRCPARAM GC1035 2.14 45.4 364.3 18.61 6.7 1 **  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 33.56S:\Projects\FPL\Port Everglades Modernization Sept1 1\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 0.00S:\Projects\FPL\Port Everglades Modernization Sept1 1\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 0.0 0 0.00 0.00 SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS2 0.00 0.00 0.00 0.0 0 0.00 23.77 SO BUILDHGT COMPRS2 23.77 23.77 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS2 0.00 0.00 0.00 0.0 0 0.00 33.25 SO BUILDWID COMPRS2 31.77 29.32 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS2 0.00 0.00 0.00 0.0 0 0.00 27.42 SO BUILDLEN COMPRS2 30.41 32.48 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 -113.90 SO XBADJ COMPRS2 -116.12 -114.81 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS2 0.00 0.00 0.00 0.0 0 0.00 12.95 SO YBADJ COMPRS2 -4.64 -22.10 0.00 0.0 0 0.00 0.00

SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT COMPRS3 0.00 0.00 0.00 0.0 0 0.00 23.77 SO BUILDHGT COMPRS3 23.77 23.77 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID COMPRS3 0.00 0.00 0.00 0.0 0 0.00 33.25 SO BUILDWID COMPRS3 31.77 29.32 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN COMPRS3 0.00 0.00 0.00 0.0 0 0.00 27.42 SO BUILDLEN COMPRS3 30.41 32.48 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 -105.75 SO XBADJ COMPRS3 -109.00 -108.93 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ COMPRS3 0.00 0.00 0.00 0.0 0 0.00 18.15 SO YBADJ COMPRS3 1.90 -14.42 0.00 0.0 0 0.00 0.00S:\Projects\FPL\Port Everglades Modernization Sept1 1\AERMOD\AAQS MHI\SO2\E-8_EXSO2.IN

Page: 4 1/18/2012 SO BUILDHGT HEATER 0.00 0.00 0.00 0.0 0 23.77 23.77 SO BUILDHGT HEATER 23.77 23.77 23.77 23.7 7 23.77 23.77 SO BUILDHGT HEATER 23.77 0.00 0.00 0.0 0 0.00 0.00 SO BUILDHGT HEATER 0.00 0.00 0.00 0.0 0 23.77 23.77 SO BUILDHGT HEATER 23.77 23.77 23.77 23.7 7 23.77 23.77 SO BUILDHGT HEATER 23.77 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID HEATER 0.00 0.00 0.00 0.0 0 32.48 33.56 SO BUILDWID HEATER 33.62 32.65 31.60 33.1 6 33.72 33.25 SO BUILDWID HEATER 31.77 0.00 0.00 0.0 0 0.00 0.00 SO BUILDWID HEATER 0.00 0.00 0.00 0.0 0 32.48 33.56 SO BUILDWID HEATER 33.62 32.65 31.59 33.1 5 33.71 33.25 SO BUILDWID HEATER 31.77 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN HEATER 0.00 0.00 0.00 0.0 0 29.32 25.98 SO BUILDLEN HEATER 21.86 17.07 13.94 19.0 6 23.60 27.42 SO BUILDLEN HEATER 30.41 0.00 0.00 0.0 0 0.00 0.00 SO BUILDLEN HEATER 0.00 0.00 0.00 0.0 0 29.32 25.98 SO BUILDLEN HEATER 21.86 17.07 13.94 19.0 6 23.60 27.42 SO BUILDLEN HEATER 30.41 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ HEATER 0.00 0.00 0.00 0.0 0 11.96 -64.60 SO XBADJ HEATER -65.56 -64.52 -62.62 28.5 5 25.22 21.12 SO XBADJ HEATER 16.38 0.00 0.00 0.0 0 0.00 0.00 SO XBADJ HEATER 0.00 0.00 0.00 0.0 0 -41.28 38.62 SO XBADJ HEATER 43.70 47.46 -89.97 -91.6 2 -90.50 -48.54 SO XBADJ HEATER -46.79 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ HEATER 0.00 0.00 0.00 0.0 0 -27.38 21.91 SO YBADJ HEATER 12.62 2.94 -6.83 2.8 0 9.37 15.65 SO YBADJ HEATER 21.46 0.00 0.00 0.0 0 0.00 0.00 SO YBADJ HEATER 0.00 0.00 0.00 0.0 0 27.38 -21.91 SO YBADJ HEATER -12.62 -2.94 2.04 -12.4 0 -26.47 -15.65 SO YBADJ HEATER -21.46 0.00 0.00 0.0 0 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_In tl_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 FINISHEDS:\Projects\FPL\Port Everglades Modernization Sept1 1\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. LAUDERDA LE/MIAMI FIU MET 2006-2010 *** 09:07:25 PAGE 862 **MODELOPTs: RegDFAULT CONC ELEV

*** THE SUM MARY 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. LAUDERDA LE/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, ZH ILL, 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) DCS:\Projects\FPL\Port Everglades Modernization Sept1 1\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. LAUDERDA LE/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, ZH ILL, 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. LAUDERDA LE/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, ZH ILL, 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. LAUDERDA LE/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 Sept1 1\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 val ues for NO2/SO2 require MULTYEAR Opt CO W362 8 COCARD:Multiyear 1h NO2/SO2 proces sing not applicable for 24-hr Ave CO W362 8 COCARD:Multiyear 1h NO2/SO2 proces sing not applicable for 3-hr Ave CN W305 47 WAKFLG:Stack height > or = EPA for mula height for SRCID: GA1035 CN W305 47 WAKFLG:Stack height > or = EPA for mula height for SRCID: GB1035 CN W305 47 WAKFLG:Stack height > or = EPA for mula height for SRCID: GC1035

************************************ *** AERMOD Finishes Successfully *** ************************************