PEEC Project (PSD-EPA-R4010) - Draft Final PSD Permit 5/2911/25/13 

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***PUBLIC NOTICE COPY***

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

Region 4 

Atlanta, Georgia 

Prevention of Significant Deterioration Permit 

For Greenhouse Gas Emissions

Permit PSD-EPA-R4010

In accordance with the provisions of the Clean Air Act (CAA), Subchapter I, Part C, 

42 U.S.C. § 7470, and the implementing Prevention of Significant Deterioration (PSD) of 

Air Quality Regulations at the Code of Federal Regulations (CFR) Title 40, Section 52.21 

(40 CFR § 52.21), the United States Environmental Protection Agency Region 4 hereby 

authorizes

Florida Power & Light Company

700 Universe Boulevard

Juno Beach, FL 33408

to construct and operate Greenhouse Gas air emissions units as a modification to the existing 

Port Everglades Plant located at 8100 Eisenhower Boulevard within the City of Hollywood, in 

Broward County, Florida.

This modification to the Port Everglades facility shall be constructed and operated in accordance 

with the terms and conditions set forth in this permit.

This permit becomes effective on DECEMBER 25, 2013[INSERT EFFECTIVE DATE].

This permit shall not relieve the owner or operator of the responsibility to comply fully with all 

applicable provisions of federal and state law.

__________ ______________________

Date Signed Beverly H. BanisterJeaneanne M. Gettle

Acting Director

Air, Pesticides, and Toxics

Management Division
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AUTHORITY

The United States Environmental Protection Agency (EPA) issues this permit pursuant to 

Subchapter I, Part C, of the Clean Air Act (CAA), 42 U.S.C. § 7470, and the implementing PSD 

Regulations at 40 CFR § 52.21. This permit is based upon application materials submitted to 

EPA by Florida Power & Light Company (FPL), dated January 23, 2012, May 8, 2012, August 

31, 2012, November 2, 2012, and November 16, 2012, supplemental submittals in the 

administrative record for this permit action, and upon the technical analysis performed by EPA.

APPLICANT

Florida Power & Light Company

700 Universe Boulevard

Juno Beach, FL 33408

PROJECT LOCATION

FPL’s project will be located at the existing Port Everglades Plant located at 8100 Eisenhower 

Boulevard within the City of Hollywood, in Broward County, Florida.

PROJECT DESCRIPTION

Florida Power & Light Company (FPL) will result in modernization of the existing Port 

Everglades Plant into a higher efficiency, lower emission, clean energy center using combined 

cycle technology (Project). This Prevention of Significant Deterioration (PSD) permit requires 

the retirement and replacement of four existing oil-fired units with one nominal 1,250 MW 3-on1 combined cycle unit, which will use natural gas. 

FPL’s existing facility consists of two nominal 200 MW fossil fuel-fired steam generating units 

(FFFSGU) (Units 1 and 2), two nominal 400 MW FFFSGU (Units 3 and 4), and 12 simple cycle 

natural gas turbines (GT1 - GT12). Units 1 through 4 are authorized to operate pursuant to 

Florida Department of Environmental Protection (FDEP) Final Title V Permit No. 0110036-009-

AV. Existing Units 1 through 4 will be retired and replaced with one nominal 1,250 MW 3-on-1

combined cycle unit. This Project includes the construction and operation of the 3-on-1 unit that 

consists of three nominal 250 MW advanced combustion turbines (CTs) and three heat recovery 

steam generators (HRSGs), which will utilize the waste heat from the CTs to produce steam to be 

utilized in a single nominal 500 MW steam turbine generator. The Project also includes the 

construction and operation of additional equipment, including an auxiliary boiler, emergency 

generators, gas compressors, fire pump engine, ultra low sulfur diesel (ULSD) fuel oil storage 

tank, circuit breakers, and temporary construction boilers.

This PSD permit for the Project requires the use of Best Available Control Technology (BACT) 

to limit emissions of greenhouse gases (GHGs), to the greatest extent feasible. 
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EQUIPMENT LIST

The following devices and activities are subject to this PSD permit:

Unit ID Description

CTs/HRSGs (3) • 1,250 MW (gross) 3-on-1 combined cycle combustion turbine generator 

(CT), with a maximum combined heat input rate of 3,034 MMBtu/hr 

(HHV)

Auxiliary Boiler

(1) • 99.8 MMBtu/hr (HHV) firing natural gas

Emergency 

Generators (2) • 2,250 kilowatt (kw) each firing ULSD fuel oil

Gas Compressors

(2)

• Three Solar Centaur 50 compressor sets, or equivalent, each including a 

natural gas turbine and natural gas compressor (only 2 compressor sets 

will operate at a time)

Fire Pump Engine

(1) • 300 horsepower (hp) firing ULSD fuel oil

Fuel OilULSD

Storage Tank (1)

• vertical fixed roof design 

• rated storage capacity of 7 million gallons (165,000 barrels)

Circuit Breakers

(2)

• Enclosed-pressure SF6 Circuit Breakers 

0.5 % per year (by weight) annual leakage rate

leak detection system

Temporary 

Construction 

Boilers (2)

• 150 MMBtu/hr (HHV) each firing natural gas

PERMIT CONDITIONS

I. PERMIT EXPIRATION

As provided in 40 CFR § 52.21(r), this PSD Permit shall become invalid if construction:

A. is not commenced (as defined in 40 CFR § 52.21(b)(9)) within 18 months after the 

approval takes effect; or

B. is discontinued for a period of 18 months or more; or 

C. is not completed within a reasonable time. 

II. PERMIT NOTIFICATION REQUIREMENTS

Pursuant to Condition IX, Permittee shall notify EPA Region 4 of the:

A. date construction is commenced, postmarked within 30 days of such date; 
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B. actual date of initial startup, as defined in 40 CFR § 60.2, postmarked within 15 days 

of such date;

C. date upon which initial performance tests will commence, in accordance with the 

provisions of Condition IX.G, postmarked not less than 30 days prior to such date. 

Notification may be provided with the submittal of the performance test protocol 

required pursuant to Condition IX.G; and 

D. date upon which initial performance evaluation of the continuous emissions 

monitoring system (CEMS) will commence in accordance with 40 CFR § 60.13(c), 

postmarked not less than 30 days prior to such date. Notification may be provided 

with the submittal of the CEMS performance test protocol required pursuant to 

Condition IX.F. 

III. FACILITY OPERATION

A. At all times, including periods of startup, shutdown, shakedown, and malfunction, 

Permittee shall, to the extent practicable, maintain and operate the facility, including 

associated air pollution control equipment, in a manner consistent with good air 

pollution control practice for minimizing emissions. Determination of whether 

acceptable operating and maintenance procedures are being used will be based on 

information available to EPA, which may include, but is not limited to, monitoring 

results, opacity observations, review of operating maintenance procedures and 

inspection of the facility. 

B. The Permittee shall operate and maintain the CTs and associated components in a 

manner consistent with good engineering practices for its full utilization.

C. As soon as practicable following initial startup of the CTs (as defined in 40 CFR § 

60.2) but prior to commencement of commercial operation (as defined in 40 CFR § 

72.2), and thereafter, the Permittee shall develop and implement an operation and 

maintenance plan for the facility, consistent with Condition III.B above. At a 

minimum, the plan shall identify measures for assessing the performance of the 

facility, the acceptable range of the plant performance measures for achieving the 

design electrical output, the methods for monitoring the plant performance measures, 

and the routine procedures for maintaining the facility in good operating condition.

IV. MALFUNCTION REPORTING

A. Permittee shall notify EPA Region 4 via the contact information provided in 

Condition X within two (2) calendar days following the discovery of any failure of air 

pollution control equipment or process equipment, or failure of a process to operate in 

a normal manner, which results in an increase in emissions above the allowable 
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emission limits stated in Condition IX of this permit.

B. In addition, pursuant to Condition X, Permittee shall provide written notification to 

EPA within fifteen (15) calendar days of any such failure described under Condition 

IV.A. This notification shall include a description of the malfunctioning equipment or 

abnormal operation, the date of the initial malfunction, the period of time over which 

emissions were increased due to the failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed in Condition IX, and the methods 

utilized to mitigate emissions and restore normal operations. 

C. Compliance with this malfunction notification provision shall not excuse or otherwise 

constitute a defense to any violation of this permit or any law or regulation such 

malfunction may cause. 

V. RIGHT OF ENTRY

The EPA Regional Administrator, and/or an authorized representative, upon the 

presentation of credentials, shall be permitted:

A. to enter the premises where the facility is located or where any records are required to 

be kept under the terms and conditions of this PSD Permit; 

B. during normal business hours, to have access to and to copy any records required to 

be kept under the terms and conditions of this PSD Permit; 

C. to inspect any equipment, operation, or method subject to requirements in this PSD 

Permit; and

D. to sample materials and emissions from the source(s).

VI. TRANSFER OF OWNERSHIP

In the event of any changes in control or ownership of the facility, this PSD Permit shall 

be binding on all subsequent owners and operators. Within 14 days of any such change in 

control or ownership, Permittee shall notify the succeeding owner and operator of the 

existence of this PSD Permit and its conditions by letter. Permittee shall send a copy of 

this letter pursuant to Condition X to EPA Region 4 within thirty (30) days of its 

issuance.

VII. SEVERABILITY

The provisions of this PSD Permit are severable, and, if any provision of the PSD Permit 

is held invalid, the remainder of this PSD Permit shall not be affected.
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VIII. ADHERENCE TO APPLICATION AND COMPLIANCE WITH OTHER 

ENVIRONMENTAL LAWS

Permittee shall construct the Project in compliance with this PSD permit, the application 

on which this permit is based, and all other applicable federal, state, and local air quality 

regulations. This PSD permit does not release the Permittee from any liability for 

compliance with other applicable federal, state and local environmental laws and

regulations, including the Clean Air Act.

IX. SPECIAL CONDITIONS

A. Endangered Species Act

In accordance with Section 7 of the Endangered Species Act, Permittee shall adhere to 

conditions set forth in the Biological Opinion issued for the Project on [INSERT 

ISSUANCE DATE]September 16, 2013 by the National Oceanic and Atmospheric 

Administration National Marine Fisheries Service. See Section XI of this permit for 

specific Terms and Conditions.

B. Air Pollution Control Equipment and Operation 

Permittee shall perform any necessary operations to minimize emissions so that emissions 

are at or below the emission limits specified in this permit. 

C. Combustion Turbine (CT) Emission Limits

1. Except as noted below under Condition IX.JD (shakedown), on and after the date of 

initial startup, Permittee shall not discharge or cause the discharge of emissions from the 

CT Unit into the atmosphere in excess of the following:

Emission Limit (per CT) 

(natural gas firing)

Emission Limit (per CT) 

(ULSDfuel oil burning)

GHG Limit 

(as CO2e)

8302 lb CO2e/MWh net output

(12-month rolling average)

1,248176 lb CO2e/MWh net output

(12-month rolling average)

*Compliance with the above limits shall be demonstrated in accordance with Condition IX.F.10.

2. Each The three CTs associated with PEEC shall not operate firing Ultra Low Sulfur 

Diesel (ULSD) more than an aggregate of 13,000 hours/year on a 12-month rolling total. 

The Permittee shall monitor and record the number of hours each CT operates on ULSD 

to be recorded monthly and totalled every month for the previous 12 months.

D. Requirements during Combustion Turbine Startup and Shutdown 

1. Startup is defined as the commencement of operation of any emissions unit which has 
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shut down or ceased operation for a period of time sufficient to cause temperature, 

pressure, chemical, or pollution control device imbalances, which result in excess 

emissions above the limits in Condition IX.C.

a. A cold startup means a startup when the CT has not been in operation during the 

preceding 48 hours. 

b. Warm and hot start-ups include all startups that are not a cold startup. 

2. Shutdown is defined as the period beginning with the lowering of equipment from normal 

operating load and lasting until fuel flow is completely off and combustion has ceased.

3. The duration of startup and shutdown periods shall not exceed the following in any 24 

hour period, for the CT unit, as verified by the CEMS:

Duration

Cold Startup 4 hours

Warm and Hot 

Startup 2 hours

Shutdown 2 hours

4. Permittee must operate the CEMS during startup and shutdown periods.

5. Permittee must record the time, date, and duration of each startup and shutdown event. 

These records must be kept for five years following the date of such event.

D. Reserved

E. Auxiliary Equipment Emission and Operating Limits and Work Practices

1. At all times, including equipment startup and shutdown, Permittee shall not discharge or 

cause the discharge of emissions from each unit into the atmosphere in excess of the 

following, and shall otherwise comply with the following specifications on a 12-month 

rolling total:

Unit ID (description) GHG Limit 

(as CO2e)

Auxiliary Boiler (1)

99.8 MMBtu/hr (HHV) 11,670 TPY
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Unit ID (description) GHG Limit 

(as CO2e)

Emergency Generators (2)

2,250 kW per engine 344 TPY

Gas Compressors (2)

5,514 hp per engine 55,313 TPY

Fire Pump Engine (1)

300 hp firewater pump 15.2 TPY

Circuit Breakers (2)

SF6 Circuit Breakers

2.25 TPYWork 

Practice Standards

Temporary Construction Boilers (2)

150 MMBtu/hr per boiler 18,350 TPY

*Compliance with the above limits shall be demonstrated in accordance with Condition IX.H.3.

2. The Auxiliary Boiler shall not operate during normal operations of the CT, except during 

periods of, or immediately following, startup. The Auxiliary Boiler shall be shut down as 

soon as practicable after the completion of any startup process as defined in Condition 

IX.D.1. Annual hours of operation for the Auxiliary Boiler shall not exceed 2,000 hours

per 12-month rolling total.

3. The Auxiliary Boiler shall undergo annual tune-ups and meet the associated requirements 

as follows (if the unit is not operating on the required date for a tune-up, the tune-up must 

be conducted within one week of startup):

a. Inspect the burner, and clean or replace any components of the burner as necessary 

(you maythe permittee may delay the burner inspection until the next scheduled unit 

shutdown, but you must inspect each burner at least once every 18 months).

b. Inspect the flame pattern, and adjust the burner as necessary to optimize the flame 

pattern. The adjustment should be consistent with the manufacturer's specifications.

c. Inspect the system controlling the air-to-fuel ratio, and ensure that it is correctly 

calibrated and functioning properly.

4. Except during an emergency, Tthe Emergency Generators shall be limited to operation of 

the engine for maintenance and testing purposesas an “emergency stationary RICE” as 

defined in 40 CFR Part 63 Subpart ZZZZ. Annual hours of operation for Emergency 

Generators, for maintenance and testing, shall not exceed 10024 hours per 12-month 

rolling total for each generator.
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5. The Gas Compressors shall be used to increase pressure from the existing natural gas 

pipeline to the CTs. Except during an emergency, only two of the three compressors will 

operate at any given time. Records of operation shall be kept in accordance with 

Condition IX.I.

6. Except during an emergency,T the Fire Pump Engine shall be limited to operation as an 

“emergency stationary RICE” as defined in 40 CFR Part 63 Subpart ZZZZof the engine 

for maintenance and testing purposes. Annual hours of operation for the Fire Pump 

Engine, for maintenance and testing, shall not exceed 24 hours per 12-month rolling total.

7. Circuit Breakers shall be used as electrical interrupters in the event of a power surge,

shall be equipped with low-density pressure alarms, and shall be visually inspected on a 

daily basis. In addition, Permittee shall implement a maintenance program that maintains 

the integrity of the breakers and minimizes SF6 emissions. shall be inspected by the 

manufacturer once every 5 years, and shall be overhauled at the end of their 20 year life 

cycle. Records of inspection shall be kept in accordance with Condition IX.I. Given that 

this is a work practice standard, no quantification of SF6 emissions is required for 

compliance with the BACT emissions limit of 2.25 tons per year of CO2e per breaker.

8. The Temporary Construction Boilers shall be limited to use only during the Project 

construction period to provide steam during construction activities that includes but is not 

limited to for HRSG cleaning and associated steam blows. Annual hours of operation for 

each the two boilers shall not exceed an aggregate of 3,0001,500 hours per 12-month 

rolling total. The Temporary Construction Boilers will be permanently shut down and 

removed from the facility once commercial operation of the Project begins.

F. Continuous Emissions Monitoring of CO2System (CEMS) for CTs

1. Permittee shall install, certify, operate and maintain monitoring systems for quantifying 

CO2 emissions from each CT in accordance with the applicable requirements of 

40 CFR part 75. Consistent with 40 CFR § 75.4(b), all applicable certification tests shall 

be completed within 180 calendar days after the date the unit commences commercial 

operation (as defined in 40 CFR § 72.2).

2. Following initial certification, the CO2 continuous monitoring systems shall be quality 

assured in accordance with the applicable requirements of 40 CFR part 75.

3. The CO2 continuous monitoring systems shall be capable of producing hourly 

determinations of CO2 mass emissions in tons per hour (tons/hr).

4. In accordance with 40 CFR § 75.62, an initial monitoring plan shall be submitted 

identifying the methodology for which CO2 mass emissions will be continuously 

monitored. The initial monitoring plan shall be submitted no later than 21 days prior to 

the initial certification tests.
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5. Permittee shall provide notifications as specified in 40 CFR § 75.61 for any event related 

to the continuous measurement of CO2.

6. Permittee shall measure and record, for each CT, the actual heat input (Btu) on an hourly 

basis in accordance with 40 CFR part 75.

7. Permittee shall measure and record, for each CT, the following on an hourly basis:

a. Net energy output rate (MW);

b. CO2 mass emission rate (tons CO2/hr);

c. Heat input rate (MMBtu/hr);

d. Unit operating time, as described in 40 CFR § 75.57(b)(2);

e. The type of fuel (natural gas or ULSD fuel oil) burned;

8. Permittee shall calculate and record, for each CT, the following on a monthly basis:

a. Monthly average CO2 emission rate (lb CO2/MWh) calculated as the sum of each 

hourly CO2 mass emission rate times the unit operating time for the hour divided by 

the sum of the recorded net energy output rates times the unit operating time for the 

hour for all hours of operation in each month. If more than one fuel is utilized in a 

month, a separate average CO2 emissions rate shall be calculated for each fuel.

b. Monthly average heat rate (Btu/kWh) calculated as the sum of each hourly heat input 

rate times the unit operating time for the hour divided by the sum of the recorded 

energy output rates times the unit operating time for the hour for all hours of 

operation in each month times 1000. If more than one fuel is utilized in a month, a 

separate average heat input rate shall be calculated for each fuel.

9. Permittee shall calculate and record, for each CT, the following on an annual basis:

A. The 12-month rolling average CO2 emission rate (lb CO2/MWh), for each fuel 

combusted in the previous 12 months, shall be calculated as the sum of each monthly 

average value times the monthly net energy output (MWh) divided by the sum of the 

net energy output (MWh) generated during the 12-month period.

A. b. The 12-month rolling average heat rate (Btu/kWh), for each fuel combusted in 

the previous 12 months, shall be calculated as the sum of each monthly average heat 

rate value times the monthly energy output (kWh) divided by the sum of the energy 

output (kWh) generated during the 12-month period.At the earliest feasible 

opportunity after first firing of CTs and before CTs commence commercial operation 

(as defined in 40 CFR § 72.2), in accordance with the recommendations of the 

equipment manufacturer and the construction contractor:
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a. Permittee shall install, calibrate, and operate a CEMS for each CT that measures stack 

gas CO2 concentrations in parts per million by volume (ppmv). The concentrations 

shall be corrected to 15% O2 on a dry basis. No later than the end of the shakedown 

period as defined in Condition IX.J. or upon commencing commercial operations, 

whichever comes first, Permittee shall also maintain, certify, and quality-assure a 

CEMS for each CT that measures stack gas CO2 concentrations in ppmv, and shall 

conduct initial certification of the CEMS in accordance with Condition IX.F.6. The 

concentrations shall be corrected to 15% O2 on a dry basis. 

The CO2 CEMS shall meet the applicable requirements of 40 CFR Part 75. 

Each CEMS shall complete a minimum of one cycle of operation (sampling, analyzing, 

and data recording) for each successive 15-minute clock-hour period.

The initial certification of the CEMS may either be conducted separately, as specified in 

40 CFR § 60.334(b)(1), or as part of the initial performance test of each emission 

unit. The CEMS must undergo and pass initial performance specification testing on or 

before the date of the initial performance test.

The CEMS shall meet the requirements of 40 CFR § 60.13. Data sampling, analyzing, 

and recording shall also be adequate to demonstrate compliance with emission limits 

during startup and shutdown.

Not less than 90 days prior to the date of initial startup of the facility, the Permittee shall 

submit to the EPA a quality assurance project plan for the certification and operation 

of the CEMS. Such a plan shall conform to EPA requirements contained in 40 CFR 

Part 60 Appendix F for CO2, and 40 CFR Part 75 Appendix B for stack flow. The 

plan shall be updated and resubmitted upon request by EPA. The plan shall specify 

how emissions during startups and shutdowns will be determined and calculated, 

including quantifying flow accurately if calculations are used.

The gas turbine CEMS shall be audited quarterly and tested annually in accordance with 

40 CFR Part 60 Appendix F, Procedure 1. Permittee shall perform a full stack 

traverse during initial run of annual RATA testing of the CEMS, with testing points 

selected according to 40 CFR Part 60 Appendix A, Method 1. 

Permittee shall submit a CEMS performance test protocol to the EPA no later than 30 

days prior to the test date to allow review of the test plan and to arrange for an 

observer to be present at the test. The performance test shall be conducted in 

accordance with the submitted protocol and any changes required by EPA. 

Permittee shall furnish the EPA a written report of the results of performance tests within 

60 days of completion via the contact information provided in Condition X. 

The stack gas volumetric flow rates shall be calculated in accordance with the fuel 
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flowmeter requirements of 40 CFR Part 75 Appendix D in combination with the 

appropriate parts of EPA Method 19.

12. Permittee shall measure and record, for each CT, the actual heat input (Btu) on an 

hourly basis.

Permittee shall measure and record, for each CT, the following:

Net energy output (MWhnet and kWhnet) on an hourly basis;

Pounds of CO2 per net energy output (lb CO2/MWhnet) on an hourly basis;

Net heat rate (Btu/kWhnet) on an hourly basis, based on total heat input for the facility;

The type of fuel (natural gas or ULSD) burned on an hourly basis;

The 12-month rolling average emission rate of lb CO2/MWhnet and Btu/kWhnet. The 12-

month rolling average shall be based on the average hourly recordings summed for 

each operating month and averaged with the respective rates from the previous 11 

months for each fuel type.

G. Performance Tests

1. Stack Tests

a. Within 60 days after achieving normal operation, but not later than 180 days after the 

initial startup of equipment, and, unless otherwise specified, annually thereafter 

(within 30 days of the initial performance test anniversary), Permittee shall conduct 

performance tests (as described in 40 CFR § 60.8) as follows:

i. CO2 emissions from each CT

b. Permittee shall submit a performance test protocol to EPA no later than 30 days prior 

to the test to allow review of the test plan and to arrange for an Agency observer to be 

present at the test. The performance test shall be conducted in accordance with the 

submitted protocol, and any changes required by EPA. 

c. Performance tests shall be conducted in accordance with the test methods set forth in 

40 CFR § 60.8 and 40 CFR Part 60 Appendix A, as modified below. In lieu of the 

specified test methods, equivalent methods may be used with prior written approval 

from EPA:

i. EPA Methods 1-4 and 3B for CO2 emissions, and

ii. the provisions of 40 CFR § 60.8(f). 

d. Upon written request and adequate justification from the Permittee, EPA may waive a 
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specific annual test and/or allow for testing to be done at less than maximum 

operating capacity.

e. For performance test purposes, sampling ports, platforms, and access shall be 

provided on the emission unit exhaust system in accordance with the requirements of 

40 CFR § 60.8(e).

f. Permittee shall furnish the EPA a written report of the results of performance tests 

within 60 days of completion to the address listed in Condition X.

G. Compliance for Combustion Turbines

For demonstrating compliance with the limits specified in Condition IX.C.1, Permittee 

shall use the procedures set forth in 40 CFR parts 75 and 98 to determine resulting GHG 

emissions (as CO2e) based on the combination of measured CO2 emissions (from 

continuous monitoring system) and calculated CO2e of other GHG pollutants [as 

specified in Condition K]. Permittee shall keep adequate records of these GHG 

emission calculations according to requirements in Condition IX.I.1.

H. Monitoring and Compliance for Auxiliary Equipment

1. Permittee shall install and maintain fuel measurement equipment, including but not 

limited to ULSD tank gauges and fuel receipts, an operational non-resettable totalizing 

mass or volumetric flow meter to measure fuel use in each fuel line for the 99.8

MMBtu/hr boiler (Auxiliary Boiler), the 2,250 kW emergency use engines (Emergency 

Generators), and the 300 hp emergency-use firewater pump (Fire Pump Engines), and the 

150 MMBtu/hr boilers (Temporary Construction Boilers). Fuel use, to shall be recorded 

monthly and totalled every month for the previous 12 months.

2. Permittee shall install and maintain an operational non-resettable elapsed time meter for 

the 99.8 MMBtu/hr boiler (Auxiliary Boiler), the 2,250 kW emergency use engines

(Emergency Generators), the 300 hp emergency-use firewater pump (Fire Pump Engine), 

and the 150 MMBtu/hr boilers (Temporary Construction Boilers) to be recorded monthly 

and totalled every month for the previous 12 months.

Permittee shall install and maintain a leak detection system on the circuit breakers that 

signals an alarm in the facility’s control room in the event that any circuit breaker loses 

more than 10% of its dielectric fluid. The owner/operator shall promptly respond to any 

alarm, investigate the circuit breaker involved, and fix any leak-tightness problems that 

caused the alarm.

3. Permittee shall use the data recorded in Conditions IX.H.1 and IX.H.2 as well as the

appropriate emission factors from 40 CFR Part 98, Subpart C, Table C-2 and the Global 

Warming Potential factors in Condition IX.K to calculate and record CO2e emissions 

from the 99.8 MMBtu/hr boiler (Auxiliary Boiler), the 2,250 kW emergency use engines 

(Emergency Generators), the 300 hp emergency-use firewater pump (Fire Pump 

Engines), and the 150 MMBtu/hr boilers (Temporary Construction Boilers).
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I. Recordkeeping and Reporting 

1. Permittee shall maintain a file of all records, data, measurements, reports, and documents 

related to the operation of the facility, including, but not limited to, the following: all 

records or reports pertaining to adjustments and/or maintenance performed on any system 

or device at the facility; all records relating to performance tests and monitoring of

auxiliary combustion equipment; and all other information required by this permit 

recorded in a permanent form suitable for inspection. 

2. Permittee shall maintain CEMS records that include the following: the occurrence and 

duration of any startup, shutdown, shakedown, or malfunction, performance testing, 

evaluations, calibrations, checks, adjustments, maintenance, duration of any periods 

during which a continuous monitoring system or monitoring device is inoperative, and 

corresponding emission measurements.

3. Permittee shall maintain records of all source tests and monitoring and compliance 

information required by this permit.

4. Permittee shall maintain records and submit a written report of all excess emissions to 

EPA semi-annually, except when: more frequent reporting is specifically required by an 

applicable subpart; or the Administrator, on a case-by-case basis, determines that more 

frequent reporting is necessary to accurately assess the compliance status of the source. 

The report is due on September 30th and March 31st and shall include the following:

a. Time intervals, data and magnitude of the excess emissions, the nature and cause (if 

known), corrective actions taken and preventive measures adopted;

b. Applicable time and date of each period during which the CEMS was inoperative

(monitor down-time), except for zero and span checks, and the nature of CEMS 

repairs or adjustments;

c. A statement in the report of a negative declaration; that is, a statement when no 

excess emissions occurred or when the CEMS has not been inoperative, repaired, or 

adjusted;

d. Any failure to conduct any required source testing, monitoring, or other compliance 

activities; and

e. Any violation of limitations on operation, including but not limited to restrictions 

on hours of operation.

5. Excess emissions shall be defined as any period in which the facility emissions exceed 

the maximum emission limits set forth in this permit.

6. A period of monitor down-time shall be any unit operating clock hour in which sufficient 

data are not obtained by the CEMS to validate the hour for CO2 according to 40 CFR Part 
PEEC Project (PSD-EPA-R4010) - Draft Final PSD Permit 5/2911/25/13 

15

75.

7. Excess emissions indicated by the CEM system, source testing, or compliance monitoring 

shall be considered violations of the applicable emission limit for the purpose of this 

permit.

8. Permittee shall record the pounds of dielectric fluid added to the circuit breakers each 

month.

9. The Permittee shall maintain a copy of the current operation and maintenance plan for the 

facility, and shall keep a copy of all prior versions of the plan for a minimum of five 

years. The Permittee shall also keep records of the monitoring data for each of the facility

performance measures and all maintenance activities; the Permittee shall maintain such 

records for a minimum of five years following the date they are created

10. Unless otherwise specified herein, all records required by this PSD Permit shall be 

retained for not less than five years following the date of such measurements, 

maintenance, reports, and/or records. These records shall be made available for review 

upon request by the Agency or authorized representative during the course of an 

inspection.

J. Shakedown Periods

The combustion turbine and auxiliary equipment emission limits and requirements in 

Conditions IX.C , IX.D, and IX.E shall not apply during combustion shakedown periods. 

Shakedown is defined as the period beginning with initial startup and ending no later than 

initial performance testing, during which the Permittee conducts operational and 

contractual testing and tuning to ensure the safe, efficient and reliable operation of the 

plant. The shakedown period shall not exceed 1890 days. The requirements of Section III 

of this permit shall apply at all times.

K. Global Warming Potential (GWP)

For the purposes of showing compliance with any GHG emission limit in this permit, the 

GWP factors listed in 40 CFR Part 98 Subpart A, Table A-1 as of the issuance date of 

this permit shall be used. The current GWP factors are listed below:

GHG Pollutant GWP Factor

CO2 1

CH4 21

N2O 310

SF6 23,900
PEEC Project (PSD-EPA-R4010) - Draft Final PSD Permit 5/2911/25/13 

16

X. AGENCY NOTIFICATIONS

All notifications, reporting or other communications relating to this permit shall be 

submitted to:

Chief

Air & EPCRA Enforcement Branch

Air, Pesticides and Toxics Management Division

U.S. EPA Region 4

61 Forsyth Street, SW

Atlanta, GA 30303

In addition, electronic copies of the above-referenced notifications and communications 

shall be submitted to the following individuals at their corresponding email address:

Name Email Phone

Jason Dressler dressler.jason@epa.gov 404-562-9208

Katy R. Forney forney.kathleen@epa.gov 404-562-9130

Heather Ceron ceron.heather@epa.gov 404-562-9185

XI. BIOLOGICAL OPINION “TERMS & CONDITIONS”

In order to be exempt from the prohibitions of Section 9 of the ESA, the permittee must comply 

with the following Terms and Conditions that implement the Reasonable and Prudent Measure

required under Section 9.4 of the Biological Opinion issued by the National Marine Fisheries 

Service on September 16, 2013. These Terms and Conditions are designed to minimize the 

effects of take on loggerhead, green, and hawksbill sea turtles.

1. FPL shall submit an annual report summarizing the number of takes, by species and life stage. 

Annual reports shall contain information on the date of the turtle encounter, the condition of the

turtle (include photographs, if available), problems encountered, mitigative actions taken

(e.g., the animal was transported to a rehabilitation facility or was released alive and

uninjured), and any other information the EPA and FPL deem relevant. This report must

be provided to NMFS’s PRD at the address provided in the RPM above and notification

of take shall be provided to NMFS at the following e-mail address within 24 hours,

referencing the present opinion by NMFS identifier number (SER-2012-657), title, and

date: takereport.nmfsser@noaa.gov.

2. FPL shall monitor the intake wells six times in a 24-hour period (every four hours) for the 

presence of sea turtles. In the event a sea turtle is found in the intake wells, FPL shall:

a. Observe the turtle to determine if it has any injuries or appears stressed or unhealthy.

b. Determine the turtle species.

c. Complete the Endangered Species Response Form, which includes taking photos of the turtle 

in the intake well (Appendix 1 of this opinion).

d. Enter the event in FPL’s Endangered Species Log. 
PEEC Project (PSD-EPA-R4010) - FinalDraft PSD Permit 11/255/29/13 17

e. For healthy turtles, FPL shall follow the procedure in Term and Condition #2.

f. For sick or injured turtles, FPL shall follow the procedure in Term and Condition #3.

g. For dead turtles, FPL shall follow the procedure in Term and Condition #4. 

h. For required documentation, FPL shall follow Term and Condition #5.

3. HEALTHY SEA TURTLES: If an apparently healthy turtle is seen in the intake well, FPL 

shall: 

a. Close the covers to the intake well. The animal should be able swim out of the area on its 

own with the assistance of sunlight entering the well through the entrance.

b. If after one hour the turtle has not left the well, reduce load as necessary and, if safe to do so, 

turn off one of the cooling water pumps to reduce the current in the well.

c. Contact all personnel listed in Appendix 2 of this opinion to notify them of the situation.

i. Classify the call as an environmental emergency.

ii. Be prepared to answer the questions found on the Endangered Species Response Form 

(Appendix 1 of the Biological Opinion dated September 16, 2013).

iii. Provide the Fleet Performance Diagnostic Center (FPDC) with information regarding the 

animal’s condition, approximate size, and apparent injuries (if any).

d. An FWC-approved Marine Turtle Permit Holder, or their designee, should arrive at PEEC 

within three hours of notification.

e. Continue to monitor the intake well every 15 minutes to determine if the turtle has left the 

well. 

f. If the turtle exits the well, another call should be made to the Marine Turtle Permit Holder. 

At this time, FPL personnel shall continue routine inspection of the intake wells every four 

hours. 

g. If the turtle remains in the well, the Marine Turtle Permit Holder will handle the animal as 

required by state and federal regulations. It may be necessary for plant personnel to work 

closely with the Marine Turtle Permit Holder in order to retrieve the animal.

h. Only plant personnel shall operate plant equipment (intake rakes, etc).

i. All normal safety precautions and equipment shall be used.

j. Depending on the water level and size of the turtle, employ one of the following methods to 

remove the turtle from the well. Use caution when handling the turtle, so as not to injure it.

k. For small turtles that can fit on the rake, carefully lift the turtle ensuring it is situated on the 

rake in such a manner that it cannot fall off. If needed and feasible, utilize the dip net with a 

long extension to assist the rake and keep the turtle from coming off the rake.

l. For larger turtles, unbolt and remove the intake well covers and deploy the Sea Turtle 

Retrieval Device lowering it with the intake crane. After ensuring the turtle is secure in the 

device, lift the device with the crane’s assistance.

m. After removing the turtle, place it in an appropriate container located in an area that complies 

with FWC’s Marine Turtle Conservation Guidelines. Ambient air temperature will determine 

the holding location of the container. 

n. The Marine Turtle Permit Holder will complete a full assessment. All data will be collected 

and recorded on either the FWC Tagging Form or the Sea Turtle Stranding and Salvage 

Network (STSSN) – Stranding Report and the Fibropapilloma Documentation Form (if 

applicable).

o. If the turtle is not tagged, the Marine Turtle Permit Holder will properly tag the animal with 

Passive Integrated Transponder (PIT) tags and flipper tags and complete a Tagging Form.

p. If the Marine Turtle Permit Holder deems the turtle healthy and all data have been collected, 

the Marine Turtle Permit Holder will release the turtle into the discharge canal at the first 

bend.
PEEC Project (PSD-EPA-R4010) - FinalDraft PSD Permit 11/255/29/13 18

4. SICK OR INJURED SEA TURTLES: If a sick or injured sea turtle is seen in the intake well, 

FPL shall: 

a. Immediately contact all personnel listed in Appendix 2 of the Biological Opinion dated 

September 16, 2013, to notify them of the situation.

i. Classify the call as an environmental emergency.

ii. Be prepared to answer the questions found on the Endangered Species Response Form 

(Appendix 1).

iii. Provide the FPDC with information regarding the animal’s condition, approximate size, 

and apparent injuries (if any).

b. The Marine Turtle Permit Holder should arrive at PEEC within three hours of notification. 

c. Continue to monitor the intake well every 15 minutes or less.

d. The Marine Turtle Permit Holder will handle the animal as required by state and federal 

regulations. It may be necessary for plant personnel to work closely with the Marine Turtle 

Permit Holder in order to retrieve the animal.

e. Only plant personnel shall operate plant equipment (intake rakes, etc).

f. All normal safety precautions and equipment shall be used.

g. Depending on the water level and size of the turtle, employ one of the following methods to 

remove the turtle from the well. Use caution when handling the turtle, so as not to injure it.

h. For small turtles that can fit on the rack, carefully lift the turtle ensuring it is situated on the 

rake in such a manner that it cannot fall off. If needed and feasible, utilize the dip net with a 

long extension to assist the rake and keep the turtle from coming off the rake.

i. For larger turtles, unbolt and remove the intake well covers and deploy the Sea Turtle 

Retrieval Device lowering it with the intake crane. After ensuring the turtle is secure in the 

device, lift the device with the crane’s assistance.

j. After removing the turtle, place it in an appropriate container located in an area that complies 

with FWC’s Marine Turtle Conservation Guidelines. Ambient air temperature will determine 

the holding location of the container.

k. The Marine Turtle Permit Holder will complete a full assessment. All data will be collected 

and recorded on either the FWC Tagging Form or the STSSN – Stranding Report and the 

Fibropapilloma Documentation Form (if applicable). If the turtle is not tagged, the Marine 

Turtle Permit Holder will properly tag the animal with PIT tags and flipper tags and complete 

a Tagging Form.

l. The Marine Turtle Permit Holder notifies FWC via the E-mail Stranding Pager: 

seaturtlestranding@myfwc.com. If there is no response, the Marine Turtle Permit Holder 

will call the FWC Hotline at 1-888-404-3922. 

m. In consultation with FWC, the Marine Turtle Permit Holder determines if the turtle needs to 

be transported to a rehabilitation facility or released.

n. If the Marine Turtle Permit Holder deems the turtle healthy and all data have been collected, 

the Marine Turtle Permit Holder will release the turtle into the discharge canal at the first 

bend.

o. If rehabilitation is required, the Marine Turtle Permit Holder will transport the animal to the 

FWC-designated rehabilitation facility.

5. DEAD SEA TURTLES: If a dead sea turtle is seen in the intake well, FPL shall: 

a. Immediately contact all personnel listed in Appendix 2 to notify them of the situation. 

i. Classify the call as an environmental emergency.

ii. Be prepared to answer the questions found on the Endangered Species Response Form 

(Appendix 1).
PEEC Project (PSD-EPA-R4010) - FinalDraft PSD Permit 11/255/29/13 19

iii. Provide the FPDC with information regarding the animal’s condition, approximate size, 

etc.

b. The Marine Turtle Permit Holder should arrive at PEEC within three hours of notification. 

c. Continue to monitor the intake well every 15 minutes.

d. The Marine Turtle Permit Holder will handle the animal as required by state and federal 

regulations. It may be necessary for plant personnel to work closely with the Marine Turtle 

Permit Holder in order to retrieve the animal.

e. Only plant personnel shall operate plant equipment (intake rakes, etc).

f. All normal safety precautions and equipment shall be used.

g. Depending on the water level and size of the turtle, employ one of the following methods to 

remove the turtle from the well. Use caution when handling the turtle, so as not to cause postmortem injuries.

h. For small turtles that can fit on the rake, carefully lift the turtle ensuring it is situated on the 

rake in such a manner that it cannot fall off. If needed and feasible, utilize the dip net with a 

long extension to assist the rake and keep the turtle from coming off the rake.

i. For larger turtles, unbolt and remove the intake well covers and deploy the Sea Turtle 

Retrieval Device lowering it with the intake crane. After ensuring the turtle is secure in the 

device, lift the device with the crane’s assistance.

j. After removing the turtle, place it in an appropriate container provided by the Marine Turtle 

Permit Holder.

k. The Marine Turtle Permit Holder will complete a full assessment. All data will be collected 

and recorded on the STSSN – Stranding Report and the Fibropapilloma Documentation Form 

(if applicable).

l. The Marine Turtle Permit Holder notifies FWC via the E-mail Stranding Pager: 

seaturtlestranding@myfwc.com. If there is no response, the Marine Turtle Permit Holder 

will call the FWC Hotline at 1-888-404-3922. 

m. In consultation with FWC, the Marine Turtle Permit Holder decides if a necropsy is required 

to determine the cause of death and if the mortality was causal to plant operation or due to 

another factor that occurred outside of the intake canal. If a necropsy is required, the Marine 

Turtle Permit Holder will transport or ship the animal to the FWC-designated veterinarian.

n. The Marine Turtle Permit Holder would be responsible for handling all of the sea turtles at 

PEEC, unless the immediate removal is essential to the safety of employees or the turtle or 

reliability of the electric power system. In order for FPL personnel to remove the turtle from 

the intake well, they must have completed the training provided by the Marine Turtle Permit 

Holder. If trained, the FPL employee may remove the turtle from the rake and place it in an 

appropriate container provided by the Marine Turtle Permit Holder. Ambient air temperature 

will determine the holding location of the container. If outside temperatures stay above 70°F, 

cover the turtle with a wet towel.

o. If the ambient temperature is below 70°F but above 60°F, place a dry towel over the turtle.

p. If ambient temperature is below 60°F, move it indoors.

q. Once the Marine Turtle Permit Holder arrives at PEEC, the procedures written above will be 

followed.

6. DOCUMENTATION

a. The original STSSN – Stranding Report and Fibropapilloma Documentation Form must be 

mailed to FWC at:

Florida STSSN Coordinator

Florida Fish and Wildlife Conservation Commission

Fish and Wildlife Research Institute
PEEC Project (PSD-EPA-R4010) - FinalDraft PSD Permit 11/255/29/13 20

19100 SE Federal Highway

Tequesta, FL 33469

b. E-mail the Stranding Report to STSSNForm@myfwc.com

c. If a tagging form is completed in the place of the STSSN – Stranding Report, it must be 

mailed to FWC at the address provided above.

d. Make four copies of both the STSSN – Stranding Report, the Tagging Form and the 

Fibropapilloma Documentation Form. One copy goes to each:

i. FPL Juno Environmental Service (JES)

ii. FPL PEEC

iii. Receiving facility

iv. Stranding folder with fax/email confirmation attached (held by the Marine Turtle Permit 

Holder).

e. A scanned copy of the Endangered Species Response Form and any photos shall be entered 

into FPL’s Endangered Species Log. The hard copy shall be returned to the Environmental 

Lead at PEEC.