Golder Associates Inc.

5100 W. Lemon Street, Suite 208

Tampa, FL 33609 USA

Tel: (813) 287-1717 Fax: (813) 287-1716 www.golder.com

Golder Associates: Operations in Africa, Asia, Australasia, Europe, North America and South America

July 26, 2013 10389556

Via E-Mail and U.S. Mail

Ms. Ana M. Oquendo

Environmental Engineer

Air Permits Office

United States Environmental Protection Agency, Region IV

Atlanta Federal Center

61 Forsyth Street

Atlanta, Georgia 30303-8960

(oquendo.ana@epamail.epa.gov)\

RE: FLORIDA SHADY HILLS GENERATING STATION PSD APPLICATION:

RESPONSE TO EMAIL REQUEST FOR ADDITIONAL INFORMATION AND

SUPPLEMENT TO PENDING APPLICATION

Dear Ms. Oquendo:

This correspondence provides the project clarifications requested by the United States Environmental 

Protection Agency (EPA), via email correspondence received on June 25, 2013, and June 28th, 2013,

concerning the Shady Hills Generating Station PSD Permit application, and constitutes a supplement to 

the pending application. Golder is submitting this information on behalf of the applicant, EFS Shady Hills 

LLC. 

1. From June 25th, 2013 Email from Ana Oquendo, EPA 

a. The maximum potential annual VOC emissions as presented in Table 2-7 of the 

permit application submitted to FDEP dated July 9, 2010, mentioned “VOC (as 

methane)”. Since methane is a GHG, please confirm whether there will be methane 

emissions actually been released from the storage tank and provide an estimate of 

methane PTE emissions for this unit.

b. Provide GHGs PTE estimates for the circuit breaker as well as for the fugitive 

emissions from the proposed on-site pipeline and natural gas supply.

Response:

a. As part of the FDEP permit application VOC emissions from the on-site fuel oil storage tank

were estimated utilizing EPA’s Tanks Program. Fuel oil is composed of heavy petroleum 

fractions C9-C20 and as such CH4 (methane) is not expected to occur as fugitive emissions 

from the fuel oil storage tank. The US Chemical Substances Inventory under the Toxic 

Substance Control Act defined Diesel Oil as “A complex combination of hydrocarbons 

produced by the distillation of crude oil.” It consists of hydrocarbons having carbon numbers 

predominantly in the range of C9-C20 and boils in the range of approximately 163-357 deg. 

C.

b. Attached Tables 5 and 6 include emission estimates for the proposed new circuit breakers 

and for the on-site piping components associated with the new CTs and supporting new 
Ms. Ana M. Oquendo. July 26, 2013

EPA 2 10389556

ancillary equipment. The information provided on the new piping components and circuit 

breakers is based on initial estimates only.

2. From June 28th, 2013 Email from Ana Oquendo, EPA “I appreciate the quick response 

to the question about the emergency generator rating. I kindly request that Table 1 

(highlighted fields) are also updated according to new numbers in Table 4. If the other 

two inquiries implicate a change in the total GHGs PTE emissions, Table 1 should be 

revised to account for those changes in emissions.”

Response: Table 1 has been updated to include GHG PTE emissions from the proposed new 

emergency generator, new gas heater, new circuit breakers, and natural gas piping associated with 

the project.

In addition to the responses provided above, Roy Belden provided additional information to EPA via email 

submitted on June 26, 2013 indicating the intent to permit the emergency generator rated at 2,500 

kW. Updated FDEP application forms pages affected by this correction are included in this submittal.

EFS Shady Hills LLC appreciates EPA’s consideration of this additional information. If you have any 

questions, please contact Mr. Roy Belden at (203) 357-6820 or Scott Osbourn at (813) 287-1717 in 

Tampa.

Sincerely, 

GOLDER ASSOCIATES INC. 

Scott Osbourn, PE Dave Larocca

Associate and Tampa Operations Manager Senior Engineer

cc: Roy Belden, EFS Shady Hills LLC (roy.belden@ge.com)

 Katy Forney, EPA Region IV (forney.kathleen@epa.gov)

 Heather Ceron, EPA Region IV (ceron.heather@epa.gov)

 

 

Attachments: Attachment 1— Updated Application Tables

Attachment 2 – Updated FDEP Application Form Pages

DL/dl/
ATTACHMENT 1

Updated Application Tables
Gross 

Heat Input Heat Input Power Output 

Unit (MMBtu/hr) (MMBtu/hr) (MW) (lb/hr) (tons/hr) (lb/hr) (tons/hr) (lb/hr) (tons/hr) (lb/hr) (tons/hr) 

(7FA.05) LHV HHV

100% Load, 59 F, 60% Relative Humidity (ISO), Natural Gas-Firing, CT Only

CT1 1,923 2,135 218 118.9 253,796 126.9 2.20E-04 0.5 0.0002 2.2E-03 4.7 0.0024 254,040 127CT2 1,923 2,135 218 118.9 253,796 126.9 2.20E-04 0.5 0.0002 2.2E-03 4.7 0.0024 254,040 127

3,846 4,269 435.8 507,591 253.8 1 0.0005 9 0.005 508,081 254 

Design Margin 5%

Performance 

Degradation Margin 3%

100 % Load, ISO, Oil-Firing, CT OnlyCT1 2,117 2,265 223 162.3 367,640 183.8 1.32E-03 3.0 0.0015 6.6E-03 15.0 0.0075 368,883 184CT2 2,117 2,265 223 162.3 367,640 183.8 1.32E-03 3.0 0.0015 6.6E-03 15.0 0.0075 368,883 184

4,234 4,530 445.3 735,281 367.6 6 0.0030 30 0.015 737,767 369 

Design Margin 5%

Performance 

Degradation Margin 3%

Annual Operating Scenario No. 1Annual Average Case Baseload, 59 F, 3390 Hours per Year of Natural Gas Firing and Zero Hours per Year of Oil Firing.

(Short TPY) 

CT1 430,598 

CT2 430,598 

Total (2 CTs) 861,196

Annual Operating Scenario No. 2Annual Average Case Baseload, 59 F, 2890 Hours per Year of Natural Gas Firing and 500 Hours per Year of Oil Firing.

(Short TPY) 

CT1 459,309 

CT2 459,309 

Total (2 CTs) 918,618

Annual Operating Scenario No. 3Annual Average Case Baseload, 59 F, 1640 Hours per Year of Natural Gas Firing and 750 Hours per Year of Oil Firing.

(Short TPY) 

CT1 Total (1 CT) 346,644 

CT Maximum Annual Emissions (Scenario No. 2) 918,618 Total Annual CO2e Emissions (Incudes Startup and Shutdown Emissions)(e) 918,618 Annual CO2e Emergency Generator 859 Annual CO2e Fuel Gas Heater 3,965 Annual CO2e Circuit Breakers 12 Annual CO2e Natural Gas Pipe Components 47 

Total 923,502 

PSD Review Threshold 75,000 

(a) Appendix G - Determination of CO2 Emissions, 40 CFR Part 75. Natural gas-firing CO2 lb/MMBtu = 1040 scf/MMBtu(HHV) x (1/385) scf CO2/lb-mole x 44 lb/lb-mole = 118.9 lb/MMBtu.

 Appendix G - Determination of CO2 Emissions, 40 CFR Part 75. Oil-firing CO2 lb/MMBtu = 1420 scf/MMBtu(HHV) x (1/385) scf CO2/lb-mole x 44 lb/lb-mole = 162.3 lb/MMBtu.

(b) Table C-2, Subpart C, 40 CFR Part 98 in effect as of 7/2013. Emission factors in kg/MMBtu were converted to lb/MMBtu by multiplying by 2.204.(c ) CO2e = CO2 + (21 x CH4) + (310 x N2O)(d) Assumes 5% margin for design basis and 3% margin for degradation between major overhauls and the life of unit. (e) TPY CO2e conservatively based on 100 % utilization at maximum load at an annual average operating case based on ISO conditions, 100% load @ 59 deg. F, 60 % relative humidity. Source: Golder, 2012. Revised 4/1/13. Revised 7/26/13.

TABLE 1. GHG Emissions for the Proposed Shady Hills Expansion Project Compared to PSD Review Threshod

CO2 Emissions (a) N2O Emissions (b) CH4 Emissions (b)

Adjusted lb/MWh for Margin(d)

CO2e Emissions (c)

Emission Emission Emission

Factor Emission Rate Factor Emission Rate Factor Emission Rate Emission Rate

(lb/MMBtu) (lb/MMBtu) (lb/MMBtu)

Adjusted lb/MWh for Margin(d)
N2O Emissions (a) CH4 Emissions 

Emission Emission Emission

Heat Input Operation Annual Heat Input Factor Annual Emissions Factor Annual Emissions Factor Annual 

Unit (MMBtu/hr) (Hr/yr) (MMBtu/yr) (lb/MMBtu) (Short tons/yr) (lb/MMBtu) (Short tons/yr) (lb/MMBtu) (Short 

Emergency Generator 21.01 500 10,505 163.0 856 1.32E-03 6.95E-03 6.6E-03 3.4Fuel Gas Heater 10 6780 67,800 116.9 3961 2.20E-04 7.47E-03 2.2E-03 7.4(a) Table C-2, Subpart C, 40 CFR Part 98. Emission factors in kg/MMBtu were converted to lb/MMBtu by multiplying by 2.204.(b ) Based on 40 CFR Part 98 in effect as of 7/2013. CO2e = CO2 + (21 x CH4) + (310 x N2O). Source: Golder, 2012; Revision 6/26/13, Emergency Generator rating = 2,500 kW.

TABLE 4. Shady Hills Expansion: GHG Emissions for the Proposed Emergency Generator and Fuel Gas Heater

CO2 Emissions (a)
TABLE 5: GHG Emission Estimates - SF6 Circuit Breakers 

300-SFMT-50Ea

Max V 362

BIL 1300

kA Interpt 50

lbs SF6 365

Annual Leakage Rate (Tons/Year) 0.00025

GWP (100 yr)b 23,900

CO2e (ton/yr) per Breaker 5.975

Total Quantity of Breakers 2

Total CO2e (ton/yr) 11.95

Notes:

a

The detailed design of the electrical components not complete, breakers have yet to be specified. 

Circuit Breakers emissions based on Mitsubishi Electronic Power Products, Inc. 300-SFMT-50Ea

b GWP factors based on Table A-1 of 40 CFR 98 Mandatory Greenhouse Gas Reporting

(40 CFR Part 98 in effect as of 7/2013).
TABLE 6: GHG Emission Estimates - Natural Gas Piping Supporting the Proposed Two New Combustion Turbines

Natural Gas Pipe Componentsa Type Equivalent Existing Unit Estimate Count Whole Gas Emissionsb CO2c 

(Eastern US) (No.) (No.)a (scf/hr/comp) (TPY) 

FGT Valve Valve 26 39 0.027 6.2E-03 

Union/Flange Connector 35 53 0.003 9.4E-04 

Transmitter Tap Connector 37 56 0.003 9.9E-04 

Filter Cap Connector 1 2 0.003 3.5E-05 

Relief Valve Pressure Relief Valve 1 2 0.04 4.7E-04 

FGT Gas Yard to New Gas Heater Valve Valve 30 45 0.027 7.2E-03 

Union/Flange Connector 29 44 0.003 7.8E-04 

Instrument Tap Connector 11 17 0.003 3.0E-04 

Relief Valves Pressure Relief Valve 3 5 0.04 1.2E-03 

Filter Caps Connector 2 3 0.003 5.3E-05 

New Gas Heater Valve Valve 45 68 0.027 1.1E-02 

Union/Flange Connector 9 14 0.003 2.5E-04 

Pipe reducer Connector 15 23 0.003 4.1E-04 

Instrument Tap Connector 30 45 0.003 8.0E-04 

Pressure Relief Valve Pressure Relief Valve 8 12 0.04 2.8E-03 

Meter Connector 2 3 0.003 5.3E-05 

Piping from old Heater to CT Fuel Gas System (1 Unit) Valve Valve 46 69 0.027 1.1E-02 

Union/Flange Connector 50 75 0.003 1.3E-03 

Instrument Tap Connector 8 12 0.003 2.1E-04 

Pressure Relief Valve Pressure Relief Valve 2 3 0.04 7.1E-04 

Filter Caps Connector 2 3 0.003 5.3E-05 

Piping from New Gas Heater to 2 New CTs

Valves Valve 82 123 0.027 2.0E-02 

Union/Flange Connector 100 150 0.003 2.7E-03 

Instrument Tap Connector 16 24 0.003 4.3E-04 

Filter Caps Connector 4 6 0.003 1.1E-04 

Subtotal 0.07 

Natural Gas Venting f Gas Vented / Event /CT No. of Events / CT No. CTs Total Gas Vented CO2 

(scf) (Events/yr) (scf/yr) (TPY) 

113 3 2 678 4.57E-04 

Total 0.07 

Notes:

aBased on existing system plus 50% margin (rounded to the nearest connector) for design uncertainty, GE P&ID M0001100.DWG, M-1100, M-1118, D-2132100, and Facility Component Datab 40 CFR Part 98 Table W-1A, Eastern USc Concentration of CO2 in natural gas is defined equal to 1.1x10-2 (40 CFR Part 98.233). CO2 TPY = Count x (scf/hr/comp) x 1.1x10-2 x (1 mol/0.7909 scf) x (44.01 g/ 1mol CO2) x (1 lb/ 453.6 g) x 8760 hr/yr x (1 ton/2000 lb)d Concentration of CH4 (Methane) in natural gas is defined equal to 0.975 (40 CFR Part 98.233)

CH4 TPY = Count x (scf/hr/comp) x 0.975 x (1 mol/0.7909 scf) x (16 g/ 1mol CH4) x (1 lb/ 453.6 g) x 8760 hr/yr x (1 ton/2000 lb)

e Global Warming Potential Factors: CO2 = 1 and CH4 = 21 (40 CFR Part 98 in effect as of 7/2013).f Based on existing CT operation experience. 
ATTACHMENT 2 

Updated FDEP Application Form Pages 
DEP Form No. 62-210.900(1) – Form 

Effective: 03/11/2010 29 

EMISSIONS UNIT INFORMATION 

Section [2] of [4] 

Emergency Generator

B. EMISSIONS UNIT CAPACITY INFORMATION 

(Optional for unregulated emissions units.) 

Emissions Unit Operating Capacity and Schedule 

1. Maximum Process or Throughput Rate: 

2. Maximum Production Rate: 

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

4. Maximum Incineration Rate: pounds/hr 

 tons/day 

5. Requested Maximum Operating Schedule: 

24 hours/day 7 days/week 

52 weeks/year 500 hours/year 

6. Operating Capacity/Schedule Comment: 

 
DEP Form No. 62-210.900(1) – Form 

Effective: 03/11/2010 31 

EMISSIONS UNIT INFORMATION 

Section [2] of [4] 

Emergency Generator

D. SEGMENT (PROCESS/FUEL) INFORMATION 

Segment Description and Rate: Segment 1 of 1

1. Segment Description (Process/Fuel Type): 

 

 Diesel

2. Source Classification Code (SCC): 

 2-01-001-02

3. SCC Units: 

1000 gallons of Distillate Oil (Diesel) Burned

4. Maximum Hourly Rate: 

 152.2

5. Maximum Annual Rate: 

 76,123

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 138

10. Segment Comment: 

 

Maximum hourly rate = 21.01 MMBtu/hr / (138 MMBtu / 1000 gal) = 152.2 gal/hr 

Maximum annual rate = 152.2 gal/hr x 500 hr/yr = 76,123 gal/hr

Segment Description and Rate: Segment of 

1. Segment Description (Process/Fuel Type): 

 

 

2. Source Classification Code (SCC): 

 

3. SCC Units: 

 

4. Maximum Hourly Rate: 

 

5. Maximum Annual Rate: 

 

6. Estimated Annual Activity 

 Factor: 

7. Maximum % Sulfur: 

 

8. Maximum % Ash: 

 

9. Million Btu per SCC Unit: 

 

10. Segment Comment: 

 
DEP Form No. 62-210.900(1) – Form 

Effective: 03/11/2010 33 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] of [4] Page [1] of [1] 

Emergency Generator CO2e 

F1. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION – 

POTENTIAL, FUGITIVE, AND ACTUAL EMISSIONS 

(Optional for unregulated emissions units.) 

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

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

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

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

Potential, Estimated Fugitive, and Baseline & Projected Actual Emissions

1. Pollutant Emitted: 

CO2e

2. Total Percent Efficiency of Control: 

 

3. Potential Emissions: 

3,436 lb/hour 859 tons/year 

4. Synthetically Limited? 

Yes No 

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

 to tons/year 

6. Emission Factor: Various, 40 CFR Part 98, See Table 4.

Reference: 40 CFR Part 98 in effect as of 7/2013

7. Emissions 

 Method Code: 

 3

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

 tons/year 

8.b. Baseline 24-month Period: 

From: To: 

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

 tons/year 

9.b. Projected Monitoring Period: 

 5 years 10 years 

10. Calculation of Emissions: 

 

See Table 4.

11. Potential, Fugitive, and Actual Emissions Comment: 

 
DEP Form No. 62-210.900(1) – Form 

Effective: 03/11/2010 34 

EMISSIONS UNIT INFORMATION POLLUTANT DETAIL INFORMATION 

Section [2] of [4] Page [1] of [1] 

Emergency Generator CO2e 

F2. EMISSIONS UNIT POLLUTANT DETAIL INFORMATION - 

ALLOWABLE EMISSIONS 

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

to a numerical emissions limitation. 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 BACT 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 859 TPY 

4. Equivalent Allowable Emissions: 

3,436 lb/hour 859 tons/year 

5. Method of Compliance: 

 Fuel monitoring and 40 CFR Part 98 Emission Factors in effect as of 7/2013. 

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

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

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

 

Allowable Emissions Allowable Emissions of 

1. Basis for Allowable Emissions Code: 

 

2. Future Effective Date of Allowable 

 Emissions: 

3. Allowable Emissions and Units: 

 

4. Equivalent Allowable Emissions: 

 lb/hour tons/year 

5. Method of Compliance: 

 

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