PEEC Project (PSD

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1 

## ***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. § 7 4 7 0

, 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.

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

with the terms and conditions set forth in this permit.

This p ermit becomes effective on DECEMBER 25, 2013 [ INSERT EFFECTIVE DATE]

.

This permit shall not relieve the owner or operator of the responsi bility to comply fully with all applicable provisions of fede ral and state law.

__________ ______________________ Date Signed Beverly H. Banister Jeaneanne M. Gettle Acting Director Air, Pesticides, and Toxics Management DivisionPEEC Project (PSD

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2 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 (FP L), 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 moderni zation of the existing Port Everglades Plant into a higher efficiency, lower emission

, clean energy center using combined cycle technology (Project)

. This Prevention of Significant Dete rioration (PSD) permit requires the retirement and replacement of four existing oil

- fired units with one nominal 1,250 MW 3

- on

1 combined cycle unit, which will use natural gas.

FPL’s existing facility consists of two nominal 200 MW fossil fuel

- fired ste am generating units (FFFSG U) (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

Flor ida Department of Environmental Protection (FDEP) Fi nal Title V Permit No. 0110036

- 009

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

- on

- 1 combined cy cle unit. Th is Project includes the construction and operation of the 3

- on

- 1 unit that

consist s of three nominal 250 MW advanced combustion turbines (CTs) and thre e heat recovery steam generators (HRSGs), which will utilize the waste hea t from the CTs to produce steam to be utilized in a single nominal 500 MW steam turbine generator. The Project also includes the

constr uction and operation of a dditional equipment

, includ ing 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.

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

to limit emissions of g reenhouse g ases (GHG s ), to the greatest extent feasible

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3 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 co mbustion 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 Oil ULSD Storage Tank (1) • ver tical fixed roof design

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

Circuit Breakers (2) • Enclosed

- pressure SF 6 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 REQUIRE MENTS

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

A. date construction is commenced, postmarked within 30 days of such date;PEEC Project (PSD

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4 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 I X.G, postmarked not less than 30 days prior to such date. Notification may be provided with the submittal of the perfo rmance test protocol required pursuant to Condition I X.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 prio r to such date

. Notification may be provided with the submittal of the CEMS performance test protocol required pursuant to

Condition I X.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 poll ution 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 ob servations, 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 th e performance of the

f

acility , the acceptable range of the plant performance measures for achieving the design electrical output, the metho ds for monitoring the plant performance measures, and the routine pr ocedures for maintaining the f acility in good operating condition.

IV. MALFUNCTION REPORTIN G

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 incr ease in emissions above the allowablePEEC Project (PSD

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5 emission limits stated in Condition I X of this permit.

B. In addition, pursuant to Condition X, Permit tee 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 I X, and the methods utilized to mitigate emissions and restore normal operations

.

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

constitut e 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. t o enter the premises where the f acility 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 term s 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 OWNERSHI P

In the event of any changes in control or ownership of the f acility, 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.PEEC Project (PSD

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6 VIII. ADHERENCE TO APPLICA TION AND COMPLIANCE WITH OTHER

ENVIRONMENTAL LAWS

Permittee shall construct th e P roject in compliance with this PSD permit, the application

o n 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.



### I X. 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 I X. J D (shakedown) , on and after the date of initial startup, Permittee shall not discharge or cause the disc harge 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 ) ( ULSD fuel oil burning )

GHG Limit

(as CO 2 e) 83 0 2 lb CO 2 e /MWh net output ( 12

- month rolling average ) 1, 2 4 8 176 lb CO 2 e /MWh net output (12

- month rolling average )

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

. 1 0

.

2. Each The three CT s associated with PEEC shall not operate firing Ultra Low Sulfur Diesel (ULSD) more than an aggregate of 1 3 ,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 re corded 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 hasPEEC Project (PSD

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7 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 startu p when the CT has not been in operation during th e 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 exce ed 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 ea ch 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 , a nd shall otherwise comply with the following specifications on a 12

- month rolling total :

Unit ID (description) GHG Limit ( as CO 2 e)

Auxiliary Boiler (1) 99.8 MMBtu/hr (HHV) 11,670 TPYPEEC Project (PSD

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8 Unit ID (description) GHG Limit ( as CO 2 e)

Emergency Generator s (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)

SF 6 Circuit Breakers 2.25 TPY Work

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

I X.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 (i f 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. I nspect the burner, and clean or replace any components o f the burner as necessary ( you may the 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 opti mize 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, T t he Emergency Generators shall be limited to operation of the engine for maintenance and testing purposes as an “emergency stationary RICE” as defined in 40 CFR Part 63 Subpart ZZZZ

. Annual hours of operation for Emergency

Generators , for maintenance and tes ting, shall not exceed 100 24 hours per 12

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9 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 I X.I

.

6. Except during an emergency, T t he Fire Pump Engine shall be limited to operation as an “emergency stationary RICE” as defined in 40 CFR Part 63 Subpart ZZZZ of 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 i ntegrity of the breakers and minimizes SF 6 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 I X.I

. Given that this is a work practice standard, no quantification of SF 6 emissions is required for compliance with the BACT emissions limit of 2.25 tons per year of CO 2 e per breaker

.

8. The Temporary Construction Boilers shall be limited to use only during the Projec t 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 boiler s shall not exceed an aggregate of 3,0 00 1,500 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 CO 2 System (CEMS) for CTs

1. Permittee shall insta ll

, certify , operate and maintain monitoring systems for quantifying

CO 2 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 CO 2 continuous monitoring systems shall be quality assured in accordance with the applicable requirements o f 40 CFR part 75.

3. The CO 2 continuous monitoring systems shall be capable of producing hourly

determinations of CO 2 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 m e thodology for which CO 2 mass emissions will be continuously monitored. The initial monitoring plan shall be submitted no later than 21 days prior to

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10 5. Permittee shall provide notifications as specified in 40 CFR § 75.61 f or any event related

to the continuous measurement of CO 2

.

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 o n an hourly basis:

a. Net energy output rate (MW);

b. CO 2 mass emission rate (tons CO 2 /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 CO 2 emission rate (lb CO 2 /MWh) calculated as the sum of each hourly CO 2 mass emission rate times the unit operating time for the hour divided by

the sum of the recorded n et 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 CO 2 emissions rate shall be calculated for each fuel.

b. Monthly average heat rate (B tu/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. I f 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 CO 2 emission rate (lb CO 2 /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) gen erated during the 12

- month period. At the earliest feasible opportunity after first fir ing 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 constr uction contractor:PEEC Project (PSD

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11 a. Permittee shall install, calibrate, and operate a CEMS for each CT that measures stack gas CO 2 concentrations in parts per million by volume (ppmv). The concentrations

shall be corrected to 15% O 2 on a dry basis. No later than the en d 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 CO 2 concentrations in ppmv, and s hall

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

concentrations shall be corrected to 15% O 2 on a dry basis.

The CO 2 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 f acility, the Permittee shall submit to the EPA a quality assuran ce 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 CO 2 , and 40 CFR Part 75 Appendix B for stack flow. The plan shall be updated and resubmitted upon requ est 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 accord ance 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 prot ocol 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 fuelPEEC Project (PSD

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12 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 (MWh

ne t and kWh net ) on an hourly basis;

Pounds of CO 2 per net energy output (lb CO 2 /MWh net ) on an hourly basis;

Net heat rate (Btu/kWh net ) 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 CO 2 /MWh net and Btu/kWh net
. 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. CO 2 e missions 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 t he 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, equivalen t methods may be used with prior written approval

from EPA:

i. EPA Methods 1

- 4 and 3B for CO 2 emissions , and

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

d. Upon written request and adequate justification from the Permittee, EPA may waive aPEEC Project (PSD

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13 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 CO 2 e) based on the combination of measured CO 2 emissions (from continuous monitoring system ) and calculated CO 2 e 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

- re settable 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, 25 0 kW emergency use engine s ( Emergency

Generators ), and the 300 hp emergency

- use firewater pump ( Fire Pump Engine s ) , and the 150 MMBtu/hr boilers (Temporary Construction Boilers) . Fuel use , to shall be recorded monthly and totalled every month for the previou s 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, 25 0 kW emergency use engine s ( 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 ala rm 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 shal l use the data recorded in Conditions IX. H.1 and IX. H.2 a s 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 CO 2 e 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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14 I. Record keeping and Reporting

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

r elated to the operation of the f acility, 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 f acility; all records relating to performance tests and monitoring of auxiliary combustion e quipment ; 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 malfun ction, 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 main tain 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 specific ally 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 30 th and March 31 st and sha ll 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, re paired, 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 defi ned as any period in which the f acility 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 th e hour for CO 2 according to 40 CFR PartPEEC Project (PSD

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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

f

acility , 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 f acility 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 oth erwise specified herein , a ll 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 I X.C

, I X.D, and I X.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 o peration of the plant

. The shakedown period shall not exceed 18 9 0 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 per mit, 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

CO 2 1

CH 4 2 1

N 2 O 310

SF 6 23,900PEEC Project (PSD

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16 X. A GENCY 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 dr essler.jason@epa.gov 404

- 562

- 9208 Katy R. Forney forney.kathleen@epa.gov 404

- 562

- 9 130

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 N ational Marine Fisheries Service on September 16, 2013 . The se T erms and C onditions are designed to minimize the effects of take on loggerhead, green, and hawksbill sea turtles.

1. FPL shall submit a n 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

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- Final Draft PSD Permit 11/25 5/29 /13 17 e. For healthy turtles, FP L 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 enter ing 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 F leet 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 notif ication.

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 in spection 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 fa ll 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 w ith 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 Gu idelines. 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

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- Final Draft PSD Permit 11/25 5/29 /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 emergenc y. 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 inta ke 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 loc ated 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 re corded 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 co mplete 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 F WC, 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 wil l 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

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- Final Draft PSD Permit 11/25 5/29 /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 equip ment (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 post

mortem 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 assi st 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 th e 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 c all 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 ou tside 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, un less 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 o utside 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 InstitutePEEC Project (PSD

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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 th e Environmental

Lead at PEEC.