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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

- R4014

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

, 42 U.S.C. § 7 4 7 0

, 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 )

, and the Federal Implementation Plan (FIP) at 40 CFR § 52.37 [effective

December 30, 2010, and published at 75 FR 82246 (Dec. 30, 2010)], the U

. S

. Environmental Protection Agency Region 4 hereby authorizes :

Tampa Electric Company

PO Box 111 Tampa , FL 33601

- 0111

to construct and operate Greenhouse Gas (GHG) air emissions units as a modification to the existing Polk Power Station located at 9 995 898 State Road 37 South, Mulberry (Polk County )

, Florida.

T his modification to the P olk Power Station shall be constructed and operated in accordance with the terms and conditions set forth in this permit.

This p ermit becomes effective on [ INSERT EFFECTIVE DATE]

.

This permit addresses GHG

- related PSD requirements only. For this Project, the State of Florida, through the Florida Department of Environmental Protection (FDEP) , retains jurisdiction over PSD permitting for regulated pollutants other than GHGs. This permit shall not relieve the owner or operator of the responsi bility to comply fully with all applica ble provisions of federal and state

law.

__________ ______________________ Date Signed Carol L. Kemker Acting Director Air, Pesticides, and Toxics Management DivisionPSD

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2 AUTHORITY

The EPA issues this permit pursuant to Subchapter I, Part C, of the Clean Air Act (CAA), 42 U.S.C. § 7470, the implementing PSD Regulations at 40 CFR § 52.21 , and the FIP at

40 CFR § 52.37 [effective December 30, 2010 and published at 75 FR 82246 (Dec. 30, 2010)]

. This permit is based upon application materials submitted to the EPA by Tampa Electric Company ( TECO ), dated October 2012 ; December 19

, 2012 ; April 15, 2013; and May 3, 2013; supplemental submittals in the administrative record for this permit action, an d upon the technical analysis performed by the EPA.

APPLICANT

Tampa Electric Company

PO Box 111 Tampa, FL 33 601

- 0111

PROJECT LOCATION

TECO ’s project will be located at the existing Polk Power Station located at 9 995 898 State Road

37 South, Mulberry (Polk County), Florida.

PROJECT DESCRIPTION

TECO will moderni z e the existing P olk Power Station (PPS) by adding higher

- efficiency, lower

emission com bined cycle technology (Project) to the four (4) existing simple cycle combustion turbines (CTs) . The Pr oject will increase the total nominal capacity of the se units from 660 to 1,160 megawatts (MW) and the total generating capacity of the PPS site to a nominal 1,420 MW ( all net values )

.

PPS currently consists of a nominal 2 6 5 0 MW (net) solid fuel

- based, integrated gasification and combined cycle plant in addition to the simple cycle CTs. The existing facility is authorized to operate pursuant to Flor ida Department of Environmental Protection (FDEP) t itle V operating

p ermit No. 1050 233

- 0 3 2 6

- AV. The Project will modify the simple cycle CTs to add combined cycle operation in a 4

- on

- 1 configuration consisting of: four (4) General Electric 7FA.03 CTs, each a nominal 165 MW (net) output; four (4) heat recovery steam generators (HRSGs), ea ch equipped with duct burners; and one (1) nominal 500 MW (net) output steam turbine generator (STG). The HRSGs will utilize the waste hea t from the CTs as well as natural gas

- fired duct

burners to produce steam to be utilized in the STG

. Other equipment i nclude: a six

- cell mechanical draft cooling tower, a 500 kilowatt ( k W) emergency generator powered by an ultra

low sulfur diesel (ULSD) fuel oil

- fired emergency generator engine, a new transmission line, and existing line upgrades.

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

to limit emissions of 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 with

Duct Burners ( 4 ) • 165 MW (net) simple cycle CTs

• 1,160 MW (net) combined cycle CTs utilizing a 500 MW (net) STG in

a 4

- on

- 1 configuration

• M aximum combined heat input rate of 8,924 million British thermal units per hour ( MMBtu/hr ) (H igher H eating V alue ) , corrected to International Standard Organization (ISO) conditions Emergency

Generator • 500 kW emergency generator ; ULSD fuel oil

- fired engine

STG • 500 MW (net) output

Circuit Breakers ( 18 ) • Totally

- e nclosed pressure systems containing sulfur hexafluoride ( SF 6 )

• 0. 5 % per year (by weight) annual leakage rate

• L eak detection system

Natural Gas Component Leaks • Fugitive GHG emissions (methane) resulting from leaks from piping components delivering natural gas to the duct burners of the HRSGs

PERMIT CONDITIONS

I. PERMIT EXPIRATION

As provided in 40 CFR § 52.21(r), this PSD p ermit 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 : SPECIAL CONDITIONS

, Permittee shall notify the EPA Region 4 of the:

A. date construction is commenced, postmarked within 30 days of such date;

B. actual date of initial setting in operation for any purpose , postmarked within 15 days of such date; andPSD

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4 C

. date upon which initial certification tests will commence

, in accordance with the provisions of Condition IX. D E , postmarked not less than 21 days prior to such date

. Notification may be provided with the submittal of the certification test protocol required pursuant to Condition I X. D E

.

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 the EPA, which may include, but is not limited to, monitoring results , opacit y 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 CT s /HRSG combined cycle

units (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 a n 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 methods 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 the EPA Region 4 via the contact information provided in

Condition X : A GENCY NOTIFICATIONS 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 emission limits stated in Condition I X of this permit.

B. In addition, pursuant to Condition X: A GENCY NOTIFICATIONS

, Permit tee shall provide written notification to the EPA within fifteen (15) calendar days of any such

failure described under Condition IV.A above

. This notification shall include a description of the malfunctioning equipment or abnormal operation, the date of the initial malfunction, t he period of time over which emissions were increased due to the failure, the cause of the failure, the estimated resultant emissions in excess of thosePSD

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5 allowed in Condition I X : SPECIAL CONDITIONS , 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. 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 p e rmit;

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 p ermit;

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

p ermit; 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 p ermit 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 p ermit and its conditions by letter

. Permittee shall send a copy of

this letter pursuant to Condition X: A GENCY NOTIFICATIONS to the EPA Region 4 within thirty (30) days of its issuance

.

VII. SEVERABILITY

The provisions of this PSD p ermit are severable, and, if any provision of the PSD p ermit is held invalid, the remainder of this PSD p ermit shall not be affected.PSD

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6 VIII. ADHERENCE TO APPLICA TION AND COMPLIANCE WITH OTHER

ENVIRONMENTAL LAWS

A. Permittee shall construct th e P roject 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 C lean Air Act.

B. If prehistoric or historic artifacts, such as pottery or ceramics, stone tools or metal implements, or any other physical remains that could be associated with Native American cultures, or early colonial or America settlement are encountered at any

time wi thin the project site area, the permitted project should cease all activities involving subsurface disturbance in the immediate vicinity o f such discoveries. Upon such discovery, P ermittee, or other designee, shall contact the Florida Department of State, Division of Historical Resources, Review and Compliance Section at 850.245.6333 or 800.847.7278, as well as the appropriate permitting agency office ( FDEP and the EPA Region 4) . Project activities shall not resume without verbal

and/or written authorizatio n from the Division of Historical Resource. In the event that unmarked human remains are encountered during permitted activities, all work shall stop immediately and the proper authorities notified in accordance with Section 872.05, Florida Statutes.



### I X. SPECIAL CONDITIONS

A. 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

.

B. Combustion Turbine Emission and Operational Limits and Work Practices

1. For maximized efficiency , the Permittee shall:

a. For t he CTs : u se inlet cooling, perform periodic burner tuning, maintain insulat ion e in critical areas per original equipment manufacturer’s standards the unit , and utilize instrumentation/controls to achieve high

- efficiency/low

- emissions performance; and

b. For the HRSGs: utilize efficient heat exchanger design, insulate all gas path surfaces exposed to ambient air, perform periodic inspections and cleaning s (as necessary) of heat exchanger surfaces per manufacturer’s specifications , and minimize steam venting and timely repair of steam leaks.PSD

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7 2. At all times, Permittee shall not discharge

, or cause the disc harge of

, emissions from any CT u nit into the atmosphere in excess of the following:

Operating Scenario GHG E mission Limit 1

[ ( per CT /HRSG (combined cycle) or CT

(simple cycle) on gross output basis ) ]

Combined Cycle/Natural Gas (w ith or w ithout Duct Burners) 877 pounds ( lb ) of carbon dioxide equivalent (C O 2 e ) per megawatt

- hour ( MWh ) (12

- month rolling average )

Combined Cycle/ULSD Fuel Oil 1,235 lb CO 2 e/MWh , corrected to ISO

conditions (3

- hour rolling average)

Simple Cycle/Natural Gas 1,320 lb CO 2 e/MWh , corrected to ISO

conditions (3

- hour rolling average)

Simple Cycle/ULSD Fuel Oil 1,868 lb CO 2 e/MWh , corrected to ISO

conditions (3

- hour rolling average)

1 Compliance with the above limits shall be demonstrated in accordance with Condition IX. D

. 10

.

3. T he duct burners ( of each HRSG ) shall be limited to 4,000 hours per 12

- month rolling period (as an average across the four HRSGs) . Permittee shall monitor and record the

number of hours the duct burners operate monthly and totalled every month for the previous 12 months.

4. Beginning the first full calendar year af ter demonstrating initial compliance in combined cycle mode, each CT shall be limited to operating 900 hours per calendar year (as an average across the four CTs) in simple cycle mode , except that:

a. During the first full calendar year, a one

- time allocatio n of 3,480 hours per CT (as an average across the four CTs) shall be available for use by Permittee for events when the STG is unavailable (including, but not limited to, planned outages, forced outages, and derates);

b. If the one

- time allocation is not ful ly used within the first full calendar year, the remainder may be carried over into the next calendar year; and

c. If the annual limit of 900 average hours per CT is not fully used in the first full calendar year (or any calendar year thereafter ) , the remainder may be added to the

current year

- end balance of the one

- time allocation and carried over into the next calendar year , but n ever to exceed 3,480 average hours per CT

.

5. Combined t he CTs shall be limited to operating 3,000 hours per 12

- month r olling period when burning ULSD fuel oil , but no more than 48 hours per rolling 24

- hour period

. Of the 3,000 hours, no more than 1,500 hours may be in simple cycle mode. Permittee shall monitor and record the number of hours each CT operates on ULSD ( as we ll as thePSD

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8 corresponding operating mode) hourly monthly and totalled every hour for the previous

24 hours and every month for the previous 12 months.

C. Auxiliary Equipment Emission and Operational Limits and Work Practices

1. The emergency generator diesel engine shall be properly operated and maintained in accordance to manufacturer’s specifications.

2. The emergency generator diesel engine shall be limited to operation of the engine for maintenance and testing purposes, except during an emergency. Ann ual hours of operation for an emergency stationary reciprocating internal combustion engine (as

defined in 40 CFR part 63, subpart ZZZZ) for maintenance and testing shall not exceed 100 hours per rolling 12

- month period. Compliance with this condition shal l be demonstrated in conjunction with Condition IX.E.1

.

3. Circuit b reakers shall be used as electrical interrupters in the event of a power surge

. Circuit breakers shall be totally

- enclosed

, equipped with pressure gauges with internal set points, and include an alarm system that signals low pressure

. Records of inspection s performed in accordance with Condition IX.E.2. shall be kept in accordance with

Condition I X. F

.

4. Piping components used for the transmission of natural gas to the duct burners of the

HRSGs s hall be inspected monthly on a daily basis for potential leaks

. Any detected leaks must be repaired immediately. Records of inspection , detected leaks, and repairs (including action taken and duration) shall be kept in accordance with Condition IX. F

.

D. Continuous Monitoring of CO 2 for CT s /HRSG Combined Cycle Units

1. Permittee shall insta ll

, and certify , operate and maintain monitoring systems for quantifying CO 2 emissions from each CT /HRSG unit 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

CT/HRSG 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 of 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 subm itted no later than 21 days prior to

the initial certification tests.

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

to the continuous measurement of CO 2

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9 6. Permittee shall measure and record, for each CT /HRSG (combined cycle) and CT (simple cycle) , the actual heat input (Btu) on an hourly basis in accordance with 40 CFR part 75.

6. 7. Permittee shall measure and record, for each CT /HRSG (combined cycle) and CT (simple cycle) , the following on an hourly basis:

a. Gros s e nergy output rate (MW);

b. CO 2 mass emission rate (tons CO 2 /hr);

c. Heat input rate (MMB tu/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;

7. 8. Permittee shall calculate and record, for each CT /HRSG when firing natural gas , 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 recorde d 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 ( 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.

8. 9. Beginning 12 months following initial startup , p P ermittee shall calculate and record, for

each CT /HRSG when firing natural gas , the following on a n monthly 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 energy output (MWh) divided by the sum of the

e nergy output (MWh) generated during the 12

- month period.

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

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10 10. For demonstrating compliance with the limits specified in Condition IX.B. 2 , Permittee

shall :

a. For combined cycle / natural gas (wi th or without duct burners) : use the procedures set

forth in 40 CFR parts 75 and 98 to determine , on a monthly basis, 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 H : GLOBAL WARMING POTENTIAL (GWP ) ]

. Permittee shall apportion the STG output (gross MW ) based on the output (gross MW ) of the

individual CTs. Permittee shall keep adequate records of these GHG emissio n calculations according to requirements in Condition IX.F.1.

b. For combined cycle /ULSD fuel oil, simple cycle/natural gas, and simple cycle/ULSD

fuel oil : use the procedures set forth in 40 CFR parts 75 and 98 to determine , initially upon startup and on a 12

- month basis thereafter, resulting GHG emissions as (CO 2 e)

based on an annual 3

- hour test (EPA Reference Test Method 3A) at 100 percent load

, corrected to ISO conditions, using the measured CO 2 emissions (from continuous monitoring system) and calculated CO 2 e of other GHG pollutants [as specified in

Condition H: GLOBAL WARMING POTENTIAL (GWP ) ]. For the combined cycle/ULSD fuel oil operating scenario, Permittee shall apportion the STG output (gross MW) based on the output (gross MW) of the individual CTs. Permittee shall keep adequate records of these GHG emission calculations according to requirements

in Condition IX.F.1.

E. Monitoring and Compliance for Auxiliary Equipment

1. Permittee shall install and maintain an operational

, non

- resettable

, elapsed

- time meter for

the e mergency g enerator diesel engine

, which shall record the total engine operating time monthly

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

.

2. Permittee shall :

a. C ontinuously monitor and record circuit breaker pressure;

b. V isually inspect, in accordance with manufacturer’s standards, circuit breakers and
components on a daily basis ;

c. Maintain, in accordance with manufacturer ’s standards, P rovide periodic maintenance

of the circuit breakers and components; and

d. R epair any leaks and replace equipment as needed

.

F. Recordkeeping 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 that are relevant to GHG emissions , including, but not limited to, the following:PSD

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11 a. A ll records or reports pertaining to adjustments and/or maintenance performed on any system or device at the f acility;

b. A ll records relating to performance tests and monitoring of auxiliary combustion equipment ; and

c. A ll other information that this permit requires the Permittee to obtain, maintain, or develop, recorded in a permanent form suitable for inspection

.

2. Permittee shall maintain continuous monitoring system 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 th is permit

.

4. Permittee shall maintain records and submit a written report of all deviations from permit requirements to the 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 30 th and March 31 st and shall include the following:

a. If applicable, t ime intervals, data and magnitude of the excess emissions, the nature and cause (if known), corrective actions taken and preventive measures adopted ;

b. If a pplicable

, the time and date of each period during which the continuous monitoring system was inoperative (monitor down

- time), except for zero and span checks, and the nature of continuous monitoring system 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 continuous monitoring system has not been inoperative, repaired, or adjusted;

d. Any failure to conduct any required source testing, monit oring, 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 emis sion limits set forth in this permit.PSD

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12 6. A period of monitor down

- time shall be any unit operating clock hour in which sufficient

data are not obtained by the continuous monitoring system to validate the hour for CO 2

.

7. Excess emissions indicated by the conti nuous monitoring system, source testing, or compliance monitoring shall be considered violations of the applicable emission limit for the purpose of this permit.

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

f

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

years

. 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

9. Unless otherwise specified herein , a ll records required by this PSD p ermit shall be

retained for not less than five (5) 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 cour se of an inspection.

G. Shakedown Periods

The combustion turbine and auxiliary equipment emission limits and requirements in

Conditions I X. B and I X. C shall not apply during combustion shakedown periods. Shakedown is defined as the period beginning with init ial 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 18 0 days. The requirements of Section III of this permit shall apply at all times.

H. 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 p art 98

, s ubpart A, Table A

- 1 as of the 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 23,900PSD

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13 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 dressler.jason@epa.gov 404

- 562

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

- 562

- 9 130

Heather Ceron ceron.heather@epa.gov 404

- 562

- 9185