State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 1 of 32 

4911-303-0051-P-01-0 

NOTE A 

Subsequent Submittals of Application No. 17924 dated January 17, 2008 

Date Description 

January 17, 2008 Original Application Submittal 

March 31, 2008 Submitted Additional Information (Modeling) 

December 3, 2008 Revised Application Submittal (Application dated January 17, 2008 

has been replaced by the application dated December 3, 2008) 

April 16, 2009 Submitted Updated HF BACT Analysis 

May 13, 2009 Submitted PM2.5 BACT Analysis 

May 19, 2009 Submitted Additional Information (PM2.5 BACT) 

May 28, 2009 Submitted Additional Information 

July 27, 2009 Submitted Additional Information (Modeling) 

August 4, 2009 Submitted Additional Information (Modeling) 

January 18, 2010 Submitted Additional Information 

March 16, 2010 Submitted Additional Information 

March 26, 2010 Submitted Additional Information 

April 1, 2010 Submitted Additional Information 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 2 of 32 

4911-303-0051-P-01-0 

NOTE B 

LIST OF EMISSION UNITS 

Emission Units Air Pollution Control Devices 

ID No. Description ID No. Description 

Combustion Sources 

S1 

Supercritical Pulverized 

Coal Fired Boiler – 8300 

MMBtu/hr Maximum Heat 

Input Capacity 

LN1 

CO2 

CO1 

CO3 

SI1 

SI2 

Low NOx Burners/Over-fire Air 

Selective Catalytic Reduction 

Fabric Filter Baghouse 

Wet Limestone Scrubber 

Sorbent Injection for Sulfuric Acid Mist 

Activated Carbon Injection for Mercury 

S45 

Ultra Low Sulfur Diesel 

Fired Auxiliary Boiler – 240 

MMBtu/hr Maximum Heat 

Input Capacity 

LN2 Low NOx Burner/Flue Gas Recirculation 

Coal Handling Particulate Sources 

A4 Coal Rail Unloading N/A Dust Suppressant and/or Water Sprays and 

Partial Enclosure 

S46 PRB Conveyor Stackout C13 Insertable Filter 

S47 Illinois # 6 Conveyor 

Stackout C14 Insertable Filter 

S40 Coal Crusher House C08 Baghouse 

S41 Tripper Deck C09 Baghouse 

A8 Active PRB Coal Pile and 

Transfer Point N/A Dust Suppressant and/or Water Sprays 

A9 Active Illinois # 6 Coal Pile 

and Transfer Point N/A Dust Suppressant and/or Water Sprays 

A6 Inactive PRB Coal Pile N/A Dust Suppressant and/or Water Sprays 

A7 Inactive Illinois # 6 Coal 

Pile N/A Dust Suppressant and/or Water Sprays 

Ash Management Particulate Sources 

S43 

Fly Ash Mechanical 

Exhausters C11 Baghouse 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 3 of 32 

4911-303-0051-P-01-0 

Emission Units Air Pollution Control Devices 

ID No. Description ID No. Description 

S37 Fly Ash Silo C05 Bin Vent Filter 

A3 Bottom Ash Transfer to Bin 

And from Bin to Truck N/A Water Sprays 

A1 Solid Material Handling-ash N/A Dust Suppressant and/or Water Sprays 

Gypsum Management Particulate Sources 

A2 Solid Material HandlingGypsum N/A Dust Suppressant and/or Water Sprays 

Limestone Management Particulate Sources 

A5 Limestone Railcar 

Unloading Station N/A Dust Suppressant and/or Water Sprays and Partial Enclosure 

S48 Limestone Stackout C15 Insertable Filter 

S42 Limestone Preparation 

Building Day Bin Silo C10 Bin Vent Filter 

A10 Limestone Pile and Transfer 

Point N/A Dust Suppressant and/or Water Sprays 

Sorbent Management Particulate Sources 

S36 SO3 Sorbent Silo C04 Bin Vent Filter 

S38 Mercury Sorbent Silo C06 Bin Vent Filter 

Pretreatment Material Management Particulate Sources 

S44 Pretreatment Soda Ash Silo C12 Bin Vent Filter 

S39 Pretreatment Hydrated Lime 

Silo C07 Bin Vent Filter 

Roadway Particulate Sources 

P1-P21 Paved Roadway Travel N/A Water sprays and/or Dust suppressant 

U1-U15 Unpaved Roadway Travel N/A Water sprays and/or Dust suppressant 

Cooling Tower Emissions 

S2-S35 Wet Cooling Towers 1-34 N/A Drift eliminators 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 4 of 32 

4911-303-0051-P-01-0 

Emission Units Air Pollution Control Devices 

ID No. Description ID No. Description 

Emergency Diesel Fired Engines 

EG1 

1500 HP Ultra Low Sulfur 

Diesel Fired Emergency 

Generator 

N/A 

EP1 

350 HP Ultra Low Sulfur 

Diesel Fired Emergency 

Firewater Pump 

N/A 

Fuel Storage Tanks 

TNK1 350,000 Gallon Ultra Low 

Sulfur Diesel Storage Tank N/A 

TNK2 750 Gallon Ultra Low Sulfur 

Diesel Storage Tank N/A 

TNK3 250 Gallon Ultra Low Sulfur 

Diesel Storage Tank N/A 

Ammonia Storage 

TNK4 25,000 Gallon Ammonia 

Storage Tank N/A 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 5 of 32 

4911-303-0051-P-01-0 

1. General Requirements 

1.1 At all times, including periods of startup, shutdown, and malfunction, the Permittee shall 

maintain and operate this source, including associated air pollution control equipment, in a 

manner consistent with good air pollution control practice for minimizing emissions. 

Determination of whether acceptable operating and maintenance procedures are being used 

will be based on information available to the Division which may include, but is not limited 

to, monitoring results, opacity observations, review of operating and maintenance procedures, 

and inspection or surveillance of the source. 

1.2 The Permittee shall not build, erect, install or use any article, machine, equipment or process 

the use of which conceals an emission which would otherwise constitute a violation of an 

applicable emission standard. Such concealment includes, but is not limited to, the use of 

gaseous diluents to achieve compliance with an opacity standard or with a standard that is 

based on the concentration of a pollutant in the gases discharged into the atmosphere. 

1.3 The Permittee shall submit a Georgia Air Quality Permit application to the Division prior to 

the commencement of any modification, as defined in 391-3-1-.01(pp), which may result in 

air pollution and which is not exempt under 391-3-1-.03(6). Such application shall be 

submitted sufficiently in advance of any critical date involved to allow adequate time for 

review, discussion, or revision of plans, if necessary. The application shall include, but not be 

limited to, information describing the precise nature of the change, modifications to any 

emission control system, production capacity and pollutant emission rates of the plant before 

and after the change, and the anticipated completion date of the change. 

1.4 Unless otherwise specified, all records required to be maintained by this Permit shall be 

recorded in a permanent form suitable for inspection and submission to the Division and shall 

be retained for at least five (5) years following the date of entry. 

1.5 In cases where conditions of this Permit conflict with each other for any particular source or 

operation, the most stringent condition shall prevail. 

1.6 The Permittee shall comply with the New Source Performance Standards (NSPS) as found in 

40 CFR 60 Subpart A - "General Provisions" and 40 CFR 60 Subpart Da - " Standards of 

Performance for Electric Utility Steam Generating Units for Which Construction is 

Commenced After September 18, 1978," for operation of the Coal Fired Boiler, S1. 

[40 CFR 60 Subparts A and Da] 

1.7 The Permittee shall comply with the 40 CFR 63, Subpart A “General Provisions” and 40 CFR 

63 Subpart B “Requirements for Control Technology Determinations for Major Sources in 

Accordance With Clean Air Act Sections, Sections 112(g) and 112(j)” for operation of the 

Coal Fired Boiler, S1. 

[40 CFR 63 Subparts A and B] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 6 of 32 

4911-303-0051-P-01-0 

1.8 The Permittee shall comply with the New Source Performance Standards (NSPS) as found in 

40 CFR 60 Subpart A - "General Provisions" and 40 CFR 60 Subpart Db - "Standards of 

Performance for Industrial-Commercial-Institutional Steam Generating Units," for operation 

of the Auxiliary Boiler, S45. 

[40 CFR 60 Subparts A and Db] 

1.9 The Permittee shall comply with the 40 CFR 63, Subpart A “General Provisions” and 40 CFR 

63 Subpart B “Requirements for Control Technology Determinations for Major Sources in 

Accordance With Clean Air Act Sections, Sections 112(g) and 112(j)” for operation of the 

Auxiliary Boiler, S45. 

[40 CFR 63 Subparts A and B] 

1.10 The Permittee shall comply with the New Source Performance Standards (NSPS) as found in 

40 CFR 60 Subpart A - "General Provisions" and 40 CFR 60 Subpart Y – “Standards of 

Performance for Coal Preparation Plants” for the coal processing and conveying equipment, 

coal storage systems, coal transfer and loading systems and open storage piles which includes 

Emission Units A4, S40, S41, S46, S47 and A6 to A9. 

[40 CFR 60 Subparts A and Y] 

1.11 The Permittee shall comply with the New Source Performance Standards (NSPS) as found in 

40 CFR 60 Subpart A - "General Provisions" and 40 CFR 60 Subpart OOO “Standards of 

Performance for Nonmetallic Mineral Processing Plants” for the Limestone Management 

Particulate Sources (Emission Units A5, S42 and S48) and associated conveying system. 

[40 CFR 60 Subparts A and OOO] 

1.12 The Permittee shall comply with the 40 CFR 60, Subpart A “General Provisions” and 40 CFR 

60 Subpart IIII “Standards of Performance for Stationary Compression Ignition Internal 

Combustion Engines” for operation of the Emergency Diesel Generator, EG1 and the 

Emergency Fire Water Pump, EP1. 

[40 CFR 60 Subparts A and IIII] 

1.13 The Permittee shall comply with the 40 CFR 63, Subpart A “General Provisions” and 40 CFR 

63 Subpart ZZZZ “National Emissions Standards for Hazardous Air Pollutants for Stationary 

Reciprocating Internal Combustion Engines [RICE]” for operation of the Emergency Diesel 

Generator, EG1 and the Emergency Fire Water Pump, EP1. 

[40 CFR 63 Subparts A and ZZZZ] 

1.14 The Permittee shall comply with all applicable provisions of the Acid Rain Program as found 

in 40 CFR 72 “Permit Regulations”, 40 CFR 73 “Sulfur Dioxide Allowance System”, 40 CFR 

75 “Continuous Emissions Monitoring”, and 40 CFR 77 “Excess Emissions” for operation of 

the Coal Fired Boiler, S1. 

[40 CFR Parts 72, 73, 75, and 77] 

1.15 The Permittee shall comply with the 40 CFR 68, “Chemical Accident Prevention Provisions” 

for operation of Ammonia Storage Tank, TNK4. 

[40 CFR 68] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 7 of 32 

4911-303-0051-P-01-0 

2. Allowable Emissions

Note: Except where an applicable requirement specifically states otherwise, the averaging times of 

any of the Emissions Limitations or Standards included in this permit are tied to or based on the 

run time(s) specified for the applicable reference test method(s) or procedures required for 

demonstrating compliance. 

2.1 Approval to construct shall become invalid if construction is not commenced within 18 

months after receipt of such approval, if construction is discontinued for a period of 18 

months or more, or if construction is not completed within a reasonable time. The Division 

may extend the 18-month period upon a satisfactory showing that an extension is justified. 

This provision does not apply to the time period between construction of the approved phases 

of a phased construction project; each phase must commence construction within 18 months 

of the projected and approved commencement date. For purposes of this Permit, the 

definition of “commence” is given in 40 CFR 52.21(b)(9). 

[40 CFR 52.21(r)(2)] 

2.2 The Notice of MACT Approval for the Coal Fired Boiler S1 and Auxiliary Boiler S45 shall 

expire if construction or reconstruction has not commenced within 18 months of issuance, 

unless the Division has granted an extension which shall not exceed an additional 12 months. 

[40 CFR 63.43(g)(4)] 

2.3 The Permittee shall prepare and submit an initial Title V Operating Permit Application for the 

operation of the facility in accordance with 40 CFR 70.5 within 12 months after commencing 

operation. The Permittee shall address potential 40 CFR 64 “Compliance Assurance 

Monitoring” applicability in its initial Title V Operating Permit Application. 

[40 CFR 64 and 40 CFR 70] 

2.4 The Permittee shall install and operate, as BACT for NOx on Coal Fired Boiler S1, Low NOx 

Burners, Over-fire Air and Selective Catalytic Reduction. 

[40 CFR 52.21(j)] 

2.5 The Permittee shall install and operate, as BACT and MACT for CO and BACT for VOC on 

Coal Fired Boiler S1, good combustion controls. 

[40 CFR 52.21(j) and 40 CFR 63 Subpart B] 

2.6 The Permittee shall install and operate, as BACT for SO2, BACT and MACT for HF and as 

MACT for HCl on Coal Fired Boiler S1, a Wet Limestone Scrubber. 

[40 CFR 52.21(j) and 40 CFR 63 Subpart B] 

2.7 The Permittee shall install and operate, as BACT for H2SO4 on Coal Fired Boiler S1, a Duct 

Sorbent Injection System. 

[40 CFR 52.21(j)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 8 of 32 

4911-303-0051-P-01-0 

2.8 The Permittee shall install and operate, as BACT for PM/PM10 and as MACT for Filterable 

PM, a Fabric Filter Baghouse and as BACT for PM2.5, a Fabric Filter Baghouse, a Duct 

Sorbent Injection System and good combustion controls on Coal Fired Boiler S1. 

[40 CFR 52.21(j) and 40 CFR 63 Subpart B] 

2.9 The Permittee shall install and operate, as BACT and MACT for Mercury on Coal Fired 

Boiler S1, an Activated Carbon Injection System. 

[391-3-1-.02(2)(ttt) and 40 CFR 63 Subpart B] 

2.10 The Permittee shall install and operate, as BACT for NOx on Auxiliary Boiler S45, Low NOx 

Burners and Flue Gas Recirculation. 

[40 CFR 52.21(j)] 

2.11 Except as provided in Condition No. 2.12, the Permittee shall only fire sub-bituminous coal 

(Powder River Basin, or PRB coal), or up to a 50/50 blend (by weight) of sub-bituminous and 

bituminous coal (washed Illinois #6) in the Coal Fired Boiler S1. Firing of bituminous and 

sub-bituminous coals with equivalent characteristics of PRB and Illinois #6 is permitted. 

[40 CFR 52.21(j) and 391-3-1-.02(2)(g)(subsumed)] 

2.12 The Permittee shall fire only ultra low sulfur diesel fuel that has a maximum sulfur content of 

15 ppm (0.0015% by weight), in Auxiliary Boiler S45 and during startup in Coal Fired Boiler 

S1. 

[40 CFR 52.21(j); 40 CFR 63 Subpart B; 391-3-1-.02(2)(g) (subsumed); 40 CFR 60.42b(k)(2) 

(subsumed) and 40 CFR 60.43b(h)(5) (subsumed)] 

2.13 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from Coal 

Fired Boiler S1, any gases which 

a. Contain Nitrogen Oxides (NOx) in excess of 0.050 lb/MMBtu on a 30-day rolling 

average. 

 [40 CFR 52.21(j); 391-3-1-.02(2)(d)(4) (subsumed) and 40 CFR 60.44Da(e)(1) 

(subsumed)] 

b. Contain Carbon Monoxide (CO) in excess of 0.10 lb/MMBtu on a 30-day rolling 

average. 

 [40 CFR 63 Subpart B and 40 CFR 52.21(j)] 

c. Contain Carbon Monoxide (CO) in excess of 0.30 lb/MMBtu on a 1-hour average. 

 [40 CFR 52.21(j)] 

d. Contain Filterable PM/PM10 in excess of 0.010 lb/MMBtu on a 24-hour rolling average. 

[40 CFR 63 Subpart B; 40 CFR 52.21(j); 391-3-1-.02(2)(d)(2) (subsumed) and 40 CFR 

60.42Da(c) (subsumed)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 9 of 32 

4911-303-0051-P-01-0 

e. Contain Total PM/PM10 in excess of 0.018 lb/MMBtu on a 3-hour average and Total 

PM2.5 in excess of 0.0123 lb/MMBtu on a 3-hour average. 

 [40 CFR 52.21(j)] 

f. Contain Sulfur Dioxide (SO2) in excess of 0.052 lb/MMBtu on a 12-month rolling 

average. 

 [40 CFR 52.21(j) and 391-3-1-.02(2)(g) (subsumed)] 

g. Contain Sulfur Dioxide (SO2) in excess of 0.069 lb/MMBtu on a 30-day rolling average. 

 [40 CFR 52.21(j); 391-3-1-.02(2)(g) (subsumed) and 40 CFR 60.43Da(i)(l) (subsumed)] 

h. Contain Sulfur Dioxide (SO2) in excess of 959 lb/hr on a 3-hour rolling average. 

 [40 CFR 52.21(j)] 

i. Contain Volatile Organic Compounds (VOC) in excess of 0.0024 lb/MMBtu on a 3-

hour average. 

 [40 CFR 52.21(j)] 

j. Contain Lead (Pb) in excess of 1.6 x 10-5 lb/MMBtu on a 3-hour average. 

 [40 CFR 52.21 Avoidance] 

k. Contain Fluorides (as HF) in excess of 1.40 x 10-4 lb/MMBtu on a 3-hour average. 

 [40 CFR 63 Subpart B and 40 CFR 52.21(j)] 

l. Contain Sulfuric Acid Mist (H2SO4) in excess of 0.004 lb/MMBtu on a 3-hour average. 

 [40 CFR 52.21(j)] 

m. Contain Mercury (Hg) in excess of 7.64 x 10-6 lb/MW-hr (gross) on a 12-month rolling 

average while firing sub-bituminous coal or a computed weighted average on a 12-

month rolling average based on the proportion of energy output in gross MW output 

contributed by each coal rank (sub-bituminous and bituminous) and its applicable Hg 

emissions limit while firing up to a 50/50 blend of sub-bituminous and bituminous coal. 

Hg emission limit of 6.0 x 10-6 lb/MW-hr (gross) shall be used for bituminous coal to 

calculate computed weighted average. 

 [40 CFR 63 Subpart B and 391-3-1-.02(2)(ttt)] 

n. Contain Hydrogen Chloride (HCl) in excess of 3.22 x 10-4 lb/MMBtu on a 3-hour 

average while firing sub-bituminous coal or a computed weighted average based on the 

proportion of MMBtu input contributed by each coal rank (sub-bituminous and 

bituminous) and its applicable HCl emissions limit while firing up to a 50/50 blend of 

sub-bituminous and bituminous coal. HCl emission limit of 2.4 x 10-3 lb/MMBtu shall 

be used for bituminous coal to calculate computed weighted average. 

[40 CFR 63 Subpart B] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 10 of 32 

4911-303-0051-P-01-0 

o. Exhibit greater than 20 percent opacity on a 6-minute average except for one 6-minute 

period per hour of not more than 27 percent opacity. 

[40 CFR 60.42Da(b) and 391-3-1-.02(2)(d)(3)] 

p. Contain Sulfur Dioxide (SO2) in excess of 0.08 lb/MMBtu on a 24-hour rolling average. 

[40 CFR 52.21(m)] 

q. Contain Filterable PM2.5 in excess of 0.00636 lb/MMBtu on a 3-hour average. 

[40 CFR 52.21(j)] 

r. Contain Nitrogen Oxides (NOx) in excess of 0.030 lb/MMBtu on a 12-month rolling 

average while firing sub-bituminous coal or a computed weighted average on a 12-

month rolling average based on the proportion of MMBtu input contributed by each coal 

rank (sub-bituminous and bituminous) and its applicable NOx emissions limit while 

firing up to a 50/50 blend of sub-bituminous and bituminous coal. NOx emissions limit 

of 0.044 lb/MMBtu shall be used for bituminous coal to calculate computed weighted 

average. This condition becomes effective 6 months after initial start-up of Coal Fired 

Boiler S1, absent approval by the Division for an extension of this date. 

[40 CFR 52.21(j)]

2.14 The Permittee shall maintain a minimum Sulfur Dioxide (SO2) removal efficiency of 97.5 

percent on a 30-day rolling average for the Wet Limestone Scrubber. 

[40 CFR 52.21(j) and 40 CFR 60.43Da(i)(l) (subsumed)] 

2.15 The Permittee shall limit Coal Fired Boiler S1 to a maximum design heat input of 8,300 

MMBtu/hr on a 1-hour average. 

[40 CFR 52.21(j)] 

2.16 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from Auxiliary 

Boiler S45, any gases which 

a. Contain Nitrogen Oxides (NOx) in excess of 0.1 lb/MMBtu on a 3-hour average. 

 [40 CFR 52.21(j)] 

b. Contain Carbon Monoxide (CO) in excess of 0.04 lb/MMBtu on a 3-hour average. 

 [40 CFR 63 Subpart B and 40 CFR 52.21(j)] 

c. Contain Filterable PM/PM10 in excess of 0.014 lb/MMBtu on a 3-hour average, Total 

PM/PM10 in excess of 0.024 lb/MMBtu on a 3-hour average and Total PM2.5 in excess 

of 0.012 lb/MMBtu on a 3-hour average. 

 [40 CFR 63 Subpart B; 40 CFR 52.21(j) and 391-3-1-.02(2)(d)(2) (subsumed)] 

d. Contain Sulfur Dioxide (SO2) in excess of 0.0017 lb/MMBtu on a 3-hour average. 

 [40 CFR 52.21(j)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 11 of 32 

4911-303-0051-P-01-0 

e. Contain Volatile Organic Compounds (VOC) in excess of 0.003 lb/MMBtu on a 3-hour 

average. 

 [40 CFR 52.21(j)] 

f. Contain Sulfuric Acid Mist (H2SO4) in excess of 6.0 x 10-5 lb/MMBtu on a 3-hour 

average. 

 [40 CFR 52.21(j)] 

g. Exhibit greater than 20 percent opacity on a 6-minute average except for one 6-minute 

period per hour of not more than 27 percent opacity. 

 [391-3-1-.02(2)(d)(3) and 40 CFR 60.43b(f)] 

2.17 After initial startup of the Coal Fired Boiler S1, the Permittee shall limit the hours of 

operation of Auxiliary Boiler S45 such that the total hours of operation does not equal to or 

exceed 876 hours during any twelve consecutive months. This condition shall take affect after 

the initial startup date for the Coal Fired Boiler S1 in accordance with the notification 

required in Condition 7.21.b. 

[40 CFR 52.21(j) and 40 CFR 60.44b(l)(1)] 

2.18 The Permittee shall install and operate, as BACT for cooling tower (Emission Units S2 to 

S35), drift eliminators and shall maintain documentation that a 0.0005% drift is guaranteed 

and limit the total dissolved solids (TDS) in the cooling tower makeup water to 3,300 mg/L. 

[40 CFR 52.21(j)] 

2.19 The Permittee shall install and operate, as BACT for PM/PM10 and PM2.5 on PRB Conveyor 

Stackout S46, Illinois # 6 Conveyor Stackout S47 and Limestone Stackout S48, an Insertable 

Filter. 

[40 CFR 52.21(j)] 

2.20 The Permittee shall install and operate, as BACT for PM/PM10 and PM2.5 on Coal Crusher 

House S40, Tripper Decker S41, Fly Ash Mechanical Exhausters S43 and Limestone 

Preparation Building S42, a baghouse. 

[40 CFR 52.21(j)] 

2.21 The Permittee shall install and operate, as BACT for PM/PM10 and PM2.5 on Fly Ash Silo 

S37, SO3 Sorbent Silo S36, Mercury Sorbent Silo S38, Pretreatment Soda Ash Silo S44 and 

Pretreatment Hydrated Lime Silo S39, a Bin Vent Filter. 

[40 CFR 52.21(j)] 

2.22 The Permittee shall take all reasonable precautions to prevent fugitive dust from becoming 

airborne from the following operations. The Permittee shall use a combination of enclosures, 

telescopic chutes, lowering wells, dust suppression systems, covering and crusting agents 

where appropriate: 

[40 CFR 52.21(j) and 391-3-1-.02(2)(n)(1)] 

a. Coal handling particulate sources (Emission Units A4, A6 to A9) 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 12 of 32 

4911-303-0051-P-01-0 

b. Ash management particulate sources (Emission Units A1 and A3) 

c. Gypsum management particulate sources (Emission Unit A2) 

d. Limestone management particulate sources (Emission Units A5 and A10) 

e. Roadway particulate sources (Emission Units P1 to P21 and U1 to U15) 

2.23 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from the Coal 

Handling Particulate Sources (Emission Units A4, A6 to A9, S40, S41, S46 and S47) and 

Coal Conveying Systems any visible emissions of which the percent opacity is equal to or 

greater than 10 percent. 

[40 CFR 52.21(j); 40 CFR 60.254(b)(1) and 391-2-1-.02(2)(n)(2) (subsumed)] 

2.24 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from 

Limestone Stackout S48, any stack emissions, which contain PM/PM10 in excess of 0.005 

gr/dscf. 

[40 CFR 52.21(j) and 40 CFR 60.672(a) (subsumed)] 

2.25 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from 

Limestone Railcar Unloading Station A5, any visible emissions of which the percent opacity 

is equal to or greater than 7 percent. 

[40 CFR 52.21(j) and 40 CFR 60.672(b)] 

2.26 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from openings 

(except for vents) of Limestone Preparation Building S42, any visible fugitive emissions of 

which the percent opacity is equal to or greater than 7 percent. 

[40 CFR 52.21(j) and 40 CFR 60.672(e)(1)] 

2.27 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from vents of 

Limestone Preparation Building Day Bin Silo S42, any emissions, which contain PM/PM10 in 

excess of 0.005 gr/dscf. 

[40 CFR 52.21(j)] 

2.28 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from PRB 

Conveyor Stackout S46, Illinois # 6 Conveyor Stackout S47, Coal Crusher House S40, 

Tripper Decker S41, Fly Ash Mechanical Exhausters S43, Fly Ash Silo S37, SO3 Sorbent Silo 

S36, Mercury Sorbent Silo S38, Pretreatment Soda Ash Silo S44 and Pretreatment Hydrated 

Lime Silo S39, any stack emissions, which contain PM/PM10 in excess of 0.005 gr/dscf. 

[40 CFR 52.21(j) and 40 CFR 60.254(b)(2) (subsumed)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 13 of 32 

4911-303-0051-P-01-0 

2.29 The Permittee shall not shall not discharge, or cause the discharge, into the atmosphere, from 

the Ash Management Particulate Sources (Emission Units A1, A3, S37 and S43) and Gypsum 

Management Particulate Sources (Emission Unit A2), any visible emissions of which the 

percent opacity is equal to or greater than 10 percent. 

[40 CFR 52.21(j); 391-3-1-.02(2)(b) (subsumed) and 391-2-1-.02(2)(n)(2) (subsumed)] 

2.30 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from the SO3

Sorbent Silo S36, Mercury Sorbent Silo S38, Pretreatment Soda Ash Silo S44, Pretreatment 

Hydrated Lime Silo S39 and Cooling Tower (Emission Units S2 to S35), any visible 

emissions the opacity of which is equal to or greater than 40 percent. 

[391-3-1-.02(2)(b)] 

2.31 The Permittee shall not discharge into or cause the discharge into the atmosphere from 

Roadway Particulate Sources (Emission Units P1 to P21 and U1 to U15), any visible 

emissions the opacity of which is equal to or greater than 20 percent. 

[391-2-1-.02(2)(n)(2)] 

2.32 The Permittee shall limit the hours of operation of the Emergency Diesel Generator EG1 and 

the Emergency Fire Water Pump EP1 such that the total hours of operation of each unit does 

not equal or exceed 500 hours during any twelve consecutive months. 

[40 CFR 52.21(j) and 391-3-1-.03(6)(b)(11)(v)] 

2.33 The accumulated non-emergency service (maintenance check and readiness testing) time for 

the Emergency Diesel Generator EG1 and the Emergency Fire Water Pump EP1 shall not 

exceed 100 hours during any twelve consecutive months for each unit. Any operation other 

than emergency operation, maintenance check and readiness testing is prohibited. 

[40 CFR 60.4211(e)] 

2.34 The Permittee shall fire only ultra low sulfur diesel fuel that has a maximum sulfur content of 

15 ppm (0.0015% by weight) in the Emergency Diesel Generator EG1 and the Emergency 

Fire Water Pump EP1. 

[40 CFR 52.21(j); 40 CFR 60.4207(b) and 391-3-1-.02(2)(g) (subsumed)] 

2.35 The Permittee shall not discharge into or cause the discharge into the atmosphere from the 

Emergency Diesel Generator EG1 and the Emergency Fire Water Pump EP1, any visible 

emissions the opacity of which is equal to or greater than 40 percent. 

[391-3-1-.02(2)(b)1] 

2.36 The Permittee shall comply with the emission limitation in 40 CFR 60 Subpart IIII “Standards 

of Performance for Stationary Compression Ignition Internal Combustion Engines” for the 

Emergency Diesel Generator, EG1 and the Emergency Fire Water Pump, EP1. The emission 

limits are listed in the following table: 

[40 CFR 52.21(j) and 40 CFR 60 Subpart IIII] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 14 of 32 

4911-303-0051-P-01-0 

g/kW-hr 

Pollutant → NMHC+NOx CO PM 

Emergency Generator, EG1 

Emission Limit → 6.4 3.5 0.2 

Emergency Fire Water Pump, EP1 

Emission Limit → 4 3.5 0.2 

2.37 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from PRB 

Conveyor Stackout S46, Illinois # 6 Conveyor Stackout S47, Coal Crusher House S40 and 

Tripper Decker S41 any stack emissions, which contain filterable PM2.5 in excess of 0.0008 

gr/dscf, from Fly Ash Mechanical Exhausters S43 and Fly Ash Silo S37 any stack emissions, 

which contain filterable PM2.5 in excess of 0.00265 gr/dscf, from SO3 Sorbent Silo S36, 

Mercury Sorbent Silo S38, Pretreatment Soda Ash Silo S44 any stack emissions, which 

contain filterable PM2.5 in excess of 0.005 gr/dscf, from Pretreatment Hydrated Lime Silo 

S39, Limestone Stackout S48 and vents of Limestone Preparation Building Day Bin Silo S42 

any stack emissions, which contain filterable PM2.5 in excess of 0.00135 gr/dscf. 

[40 CFR 52.21(j)] 

2.38 The Permittee shall prepare and operate a fugitive coal dust emissions control plan for Open 

Storage Piles (Emission Units A6 to A9), which includes the equipment used in the loading, 

unloading, and conveying operations at the Coal Preparation Plant. 

[40 CFR 60.254(c)(2)] 

3. Fugitive Emissions 

3.1 The Permittee shall take all reasonable precautions with any operation, process, handling, 

transportation, or storage facilities to prevent fugitive emissions of air contaminants. 

4. Process & Control Equipment 

Not applicable. 

5. Monitoring 

5.1 Any continuous monitoring system required by the Permit shall be in continuous operation 

and data recorded as set forth in this Permit during all periods of operation of the affected 

facility except for continuous monitoring system breakdowns and repairs. Data shall be 

recorded during calibration checks and zero and span adjustments. Maintenance or repair shall 

be conducted in the most expedient manner to minimize the period during which the system is 

out of service. 

[391-3-1-.02(6)(b)1] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 15 of 32 

4911-303-0051-P-01-0 

5.2 The Permittee shall install, calibrate, maintain, and operate a system to continuously monitor 

and record the indicated pollutants on the following equipment. Each system shall meet the 

applicable performance specification(s) of the Division’s monitoring requirements. 

a. A Continuous Emissions Monitoring System (CEMS) for measuring NOx emissions 

discharged to the atmosphere from the Coal Fired Boiler, S1. The 1-hour average NOx 

emissions rates shall also be recorded in pound per million Btu heat input. 

[40 CFR 52.21; 40 CFR 60.49Da(c)(1) and 391-3-1-.02(6)(b)1] 

b. A Continuous Emissions Monitoring System (CEMS) for measuring SO2 emissions 

from the Coal Fired Boiler, S1 at both the inlet and outlet of the SO2 control device. The 

1-hour average SO2 emissions rates shall also be recorded in pound per million Btu heat 

input. 

[40 CFR 52.21; 40 CFR 63 Subpart B; 40 CFR 60.49Da(b) and 391-3-1-.02(6)(b)1] 

c. A Continuous Emissions Monitoring System (CEMS) for measuring Filterable 

Particulate matter emissions discharged to the atmosphere from the Coal Fired Boiler, 

S1. The 1-hour average Filterable Particulate matter emissions rates shall also be 

recorded in pound per million Btu heat input. 

[40 CFR 52.21; 40 CFR 63 Subpart B; 40 CFR 60.48Da(p) and 391-3-1-.02(6)(b)1] 

d. A Continuous Emissions Monitoring System (CEMS) for measuring CO emissions 

discharged to the atmosphere from the Coal Fired Boiler, S1. The 1-hour average CO 

emissions rates shall also be recorded in pound per million Btu heat input. 

[40 CFR 52.21; 40 CFR 63 Subpart B and 391-3-1-.02(6)(b)1] 

e. For the purpose of this Permit, a valid hour of emissions data means any 60-minute 

period commencing on the hour and it must be based on at least 30 minutes of operation 

and include at least 2 data points representing two 15-minute periods. 

[391-3-1-.02(6)(b)1] 

f. A Continuous Monitoring System for measuring oxygen or carbon dioxide at each 

location where SO2, PM, CO or NOx emission monitors are required. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

g. A Continuous Emissions Monitoring Systems (CEMS) for measuring Mercury 

emissions discharged to the atmosphere from the Coal Fired Boiler, S1. The 1-hour 

average Mercury emissions rates shall also be recorded in pound per MW-hr electrical 

output. 

[40 CFR 52.21; 40 CFR 63 Subpart B and 391-3-1-.02(6)(b)1] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 16 of 32 

4911-303-0051-P-01-0 

h. If at any time prior to the commencement of operations of the facility, the Division 

determines that a Continuous Emissions Monitoring System (CEMS) exists that can 

reliably and accurately measure hydrochloric acid and/or hydrogen fluoride emissions 

from the Coal Fired Boiler S1 in the operating concentrations required by this permit, 

then the Permittee shall install such device(s) no later than 12 months following receipt 

of written notice from the Division or prior to the startup of the Coal Fired Boiler, S1, 

whichever is later. Any written notice from the Division shall include the basis (e.g., 

example installations) supporting the Division’s determination. The CEMS(s) shall 

measure and record the hydrochloric acid and/or hydrogen fluoride emissions 

discharged to the atmosphere from the Coal Fired Boiler, S1. The one-hour average 

hydrochloric acid emissions and/or hydrogen fluoride rates shall also be recorded in 

pound per million Btu heat input. 

[391-3-1-.02(6)(b)1] 

5.3 The Permittee shall install, calibrate, maintain, and operate monitoring devices for the 

measurement of the indicated parameters on the following equipment. Data shall be recorded 

at the frequency specified below. Where such performance specification(s) exist, each system 

shall meet the applicable performance specification(s) of the Division’s monitoring 

requirements. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The cumulative total hours of operation, during all periods of operation, for the auxiliary 

boiler S45. Data shall be recorded monthly. 

b. The heat input to Coal Fired Boiler, S1. Data shall be recorded hourly using heat input 

determined in accordance with 40 CFR 75. 

c. The gross electrical output in MW for the Power Plant. Data shall be recorded on a 

continuous basis. 

5.4 The Permittee shall install, calibrate, maintain, and operate a non-resettable continuous 

monitoring system (or device) for the Emergency Diesel Generator, EG1 and the Emergency 

Fire Water Pump, EP1 to track the hours operated during emergency service and the hours of 

operation in non-emergency service (maintenance and/or testing), to record the reason the 

engine was in operation during those time, and to record the cumulative total hours of 

operation. Data shall be recorded monthly. Each system shall meet the applicable 

performance specification(s) of the Division’s monitoring requirements. 

[40 CFR 60.4209 and 391-3-1-.02(6)(b)1] 

5.5 The Permittee shall perform the monitoring on Limestone stackout S48 and the vents of 

Limestone Preparation Building Day Bin Silo S42, according to the methods and procedures 

contained in 40 CFR 60.674(c), (d) or (e). 

[40 CFR 52.21, 40 CFR 60 Subpart OOO and 391-3-1-.02(6)(b)1] 

5.6 The Permittee shall perform periodic inspection of dust suppression system to control fugitive 

emissions from the Limestone Railcar Unloading Station A5 and from openings (except for 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 17 of 32 

4911-303-0051-P-01-0 

vents) from Limestone Preparation Building Day Bin Silo S42, according to the methods and 

procedures contained in 40 CFR 60.674(b). 

[40 CFR 52.21, 40 CFR 60 Subpart OOO and 391-3-1-.02(6)(b)1] 

5.7 The Permittee shall install, calibrate, maintain, and operate a system to continuously monitor 

and record scrubbant pH on the Wet Limestone Scrubber. 

[40 CFR 63 Subpart B and 391-3-1-.02(6)(b)1] 

5.8 The Permittee shall install, calibrate, maintain, and operate a system to continuously monitor 

and record H2SO4 sorbent injection rate. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

5.9 The Permittee shall perform an analysis of the cooling tower makeup water to measure the 

total dissolved solids (TDS). The measurement shall be performed and recorded during each 

calendar quarter. 

[40 CFR 52.21(j) and 391-3-1-.02(6)(b)1] 

 

6. Performance Testing 

6.1 The Permittee shall cause to be conducted a performance test at any specified emission point 

when so directed by the Division. The following provisions shall apply with regard to such 

tests: 

a. All tests shall be conducted and data reduced in accordance with applicable procedures 

and methods specified in the Division’s Procedures for Testing and Monitoring Sources 

of Air Pollutants. 

b. All test results shall be submitted to the Division within sixty (60) days of the 

completion of testing. 

c. The Permittee shall provide the Division thirty (30) days prior written notice of the date 

of any performance test(s) to afford the Division the opportunity to witness and/or audit 

the test, and shall provide with the notification a test plan in accordance with Division 

guidelines. 

d. All monitoring systems and/or monitoring devices required by the Division shall be 

installed, calibrated and operational prior to conducting any performance test(s). For 

any performance test, the Permittee shall, using the monitoring systems and/or 

monitoring devices, acquire data during each performance test run. All monitoring 

system and/or monitoring device data acquired during the performance testing shall be 

submitted with the performance test results. 

6.2 The methods for the determination of compliance with emission limits listed under Section 

2.0 are as follows: 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 18 of 32 

4911-303-0051-P-01-0 

a. Method 1 shall be used for the determination of sample point locations, 

b. Method 2 shall be used for the determination of stack gas flow rate, 

c. Method 3 shall be used for the determination of stack gas molecular weight, 

d. Method 3B shall be used for the determination of the emissions rate correction factor or 

excess air, Method 3A may be used as an alternative, 

e. Method 4 shall be used for the determination of stack gas moisture, 

f. Method 5 or Method 17, as applicable, shall be used for the determination of Particulate 

Matter concentration from the Material Handling and Storage Facilities, 

g. Method 5 or Method 17, as applicable in conjunction with Method 202 shall be used for 

the determination of total PM/PM10 concentration, 

h. Method 5 or Method 17, as applicable in conjunction with Method 202 shall be used for 

the determination of total PM2.5 concentration until the Director approves a test method 

for the determination of PM2.5, 

i. Method 7 or 7E for the determination of nitrogen oxide concentration from the 

Auxiliary Boiler, S45, 

j. Method 8 or CTM 013 shall be used for the determination of sulfur acid mist emissions, 

k. Method 9 and the procedures contained in Section 1.3 of the Division’s Procedures for 

Testing and Monitoring Sources of Air Pollutants shall be used for the determination of 

opacity, 

l. Method 10 shall be used for the determination of carbon monoxide concentration, 

m. Method 19 shall be used for the determination of particulate matter, carbon monoxide, 

sulfur dioxide, and nitrogen oxides emission rates and to determine sulfur dioxide 

removal efficiency, 

n. Method 25A shall be used to determine total organic compounds and to calculate 

volatile organic compound emissions, 

o. Method 18 shall be used for the determination of methane emissions, 

p. Method 26A shall be used for the determination of hydrogen fluoride and hydrogen 

chloride emissions, 

q. Method 29 shall be used for the determination of lead emissions, 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 19 of 32 

4911-303-0051-P-01-0 

r. Method 22 shall be used for the determination of fugitive emissions from Material 

Handling Sources, 

s. Compliance with the NOx limits in Condition 2.13.a and 2.13.r, SO2 limits in Condition 

2.13.f, 2.13.g, 2.13.h and 2.13.p and the removal efficiency for Wet Limestone Scrubber 

in Condition 2.14 shall be determined using the CEMS required by Condition 5.2. 

[40 CFR 63 Subpart B; 40 CFR 52.21; 40 CFR 60.49Da and 391-3-1-.02(6)(b)1] 

t. Compliance with the CO limit in Condition 2.13.c shall be determined using the CEMS 

required by Condition 5.2. 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

u. Compliance with the filterable PM limit in Condition 2.13.d shall be determined using 

the CEMS required by Condition 5.2. 

[40 CFR 63 Subpart B; 40 CFR 52.21; 40 CFR 60.48Da(p) and 391-3-1-.02(6)(b)1] 

v. [Reserved] 

w. Compliance with the mercury limit in Condition 2.13.m shall be determined using the 

CEMS required by Condition 5.2. 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

Minor changes in methodology may be specified or approved by the Director or his/her 

designee when necessitated by process variables, changes in facility design, or improvement 

or corrections, which, in his opinion, render those methods or procedures, or portions thereof, 

more reliable. 

[391-3-1-.02(3)(a)] 

6.3 Within 60 days after achieving the maximum production rate on each coal type (subbituminous coal and a 50/50 blend of sub-bituminous and bituminous coal) in Coal Fired 

Boiler S1, but not later than 180 days after the initial startup of the boiler, the Permittee shall 

conduct the following performance tests and furnish to the Division a written report of the 

results of such performance tests: 

[391-3-1-.02(3)] 

a. Performance test on Coal Fired Boiler S1, for volatile organic compounds at base load 

and at 50 percent load to verify compliance with Condition 2.13.i. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

b. Performance tests on Coal Fired Boiler S1, for PM/PM10 to verify compliance with 

Condition 2.13.e. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 20 of 32 

4911-303-0051-P-01-0 

c. Performance tests on Coal Fired Boiler S1, for PM2.5 to verify compliance with 

Conditions 2.13.e and 2.13.q. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

d. Performance test on Coal Fired Boiler S1, for fluoride emissions (as HF) to verify 

compliance with Condition 2.13.k. 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

e. Performance test on Coal Fired Boiler S1, for sulfuric acid mist to verify compliance 

with Condition 2.13.l. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

f. Performance test on Coal Fired Boiler S1, for hydrochloric acid to verify compliance 

with Condition 2.13.n. 

[40 CFR 63 Subpart B and 391-3-1-.02(6)(b)1] 

g. Performance test on Coal Fired Boiler S1, for lead to verify compliance with Condition 

2.13.j. 

[40 CFR 52.21 avoidance and 391-3-1-.02(6)(b)1] 

h. In addition to the initial performance tests, the Permittee shall conduct performance tests 

as described in Condition 6.3.a. through 6.3.g. on an annual basis. 

6.4 Within 60 days after achieving the maximum production rate at which the Auxiliary Boiler, 

S45, will be operated, but not later than 180 days after the initial startup of the boiler, the 

Permittee shall conduct the following performance tests and furnish to the Division a written 

report of the results of such performance tests: 

[391-3-1-.02(3)] 

a. Performance test on the Auxiliary Boiler, S45, for nitrogen oxide to verify compliance 

with Condition No. 2.16.a. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

b. Performance test on the Auxiliary Boiler, S45, for carbon monoxide to verify 

compliance with Condition No. 2.16.b. 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

c. Performance tests on the Auxiliary Boiler, S45, for PM/PM10 and PM2.5 to verify 

compliance with Condition No. 2.16.c. 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

d. Performance test on the Auxiliary Boiler, S45, for sulfur dioxide or fuel sampling to 

verify compliance with Condition No. 2.16.d. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 21 of 32 

4911-303-0051-P-01-0 

e. Performance test on the Auxiliary Boiler, S45, for volatile organic compounds to verify 

compliance with Condition No. 2.16.e. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

f. Performance test on the Auxiliary Boiler, S45, for sulfuric acid mist to verify 

compliance with Condition No. 2.16.f. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

g. Performance test on the Auxiliary Boiler, S45, for opacity to verify compliance with 

Condition No. 2.16.g. 

[391-3-1-.02(6)(b)1 and 40 CFR Subpart Db] 

6.5 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup, the Permittee shall conduct the 

performance test on the Coal Handling Particulate Sources (Emission Units A4, A6 to A9, 

S40, S41, S46 and S47) and coal conveying systems, for opacity to verify compliance with 

Condition No. 2.23 and furnish to the Division a written report of the results of the 

performance test. Testing shall be conducted according to the methods and procedures 

contained in 40 CFR 60.254. 

 [40 CFR 52.21, 40 CFR 60.254 and 391-3-1-.02(3)] 

 

6.6 The Permittee shall maintain records showing the guaranteed manufacturer's specifications for 

the insertable filters and/or bin vent filters on the PRB Conveyor Stackout S46, Illinois # 6 

Conveyor Stackout S47, Fly Ash Silo S37, SO3 Sorbent Silo S36, Mercury Sorbent Silo S38, 

Pretreatment Soda Ash Silo S44, Pretreatment Hydrated Lime Silo S39, Limestone stackout 

S48 and the vents of Limestone Preparation Building Day Bin Silo S42. These records shall 

be used to demonstrate compliance with the PM limits in Conditions 2.24, 2.27 and 2.28. 

These records shall be maintained in a format suitable for inspection or submittal to the 

Division. 

 [40 CFR 52.21 and 391-3-1-.02(3)] 

6.7 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup, the Permittee shall conduct 

performance testing on the Limestone Railcar Unloading Station A5 and the openings (except 

for vents) of Limestone Preparation Building Day Bin Silo S42, for opacity to verify 

compliance with Condition No. 2.25 and 2.26 and furnish to the Division a written report of 

the results of the performance test. Testing shall be conducted according to the methods and 

procedures contained in 40 CFR 60.675. 

[40 CFR 52.21, 40 CFR 60.675 and 391-3-1-.02(3)] 

6.8 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup, the Permittee shall conduct 

performance testing on the Coal Crusher House S40, Tripper Decker S41 and Fly Ash 

Mechanical Exhausters S43 for Particulate Matter to verify compliance with Condition No. 

2.28 and furnish to the Division a written report of the results of the performance test. 

[40 CFR 52.21 and 391-3-1-.02(3)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 22 of 32 

4911-303-0051-P-01-0 

6.9 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup (and annually thereafter), the 

Permittee shall conduct tests for HF and HCl on the Wet Limestone Scrubber. During tests, 

the Permittee shall use pH monitor per Condition 5.7 to determine average pH from test runs. 

The Permittee shall furnish to the Division a written report of the results of the test. 

[40 CFR 52.21, 40 CFR 63 Subpart B and 391-3-1-.02(3)] 

6.10 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup, the Permittee shall conduct 

performance tests for sulfuric acid mist. During tests, the Permittee shall use sorbent injection 

rate monitor per Condition 5.8 to determine average sorbent injection rate from test runs. The 

Permittee shall furnish to the Division a written report of the results of the performance test. 

[40 CFR 52.21 and 391-3-1-.02(3)] 

6.11 Within 60 days after achieving the maximum production rate at which the sources will be 

operated, but not later than 180 days after the initial startup, the Permittee shall conduct 

performance testing on the Coal Crusher House S40, Tripper Decker S41 and Fly Ash 

Mechanical Exhausters S43 for PM2.5 to verify compliance with Condition No. 2.37 and 

furnish to the Division a written report of the results of the performance test. 

[40 CFR 52.21 and 391-3-1-.02(3)] 

6.12 The Permittee shall maintain records showing the guaranteed manufacturer's specifications for 

the insertable filters and/or bin vent filters on the PRB Conveyor Stackout S46, Illinois # 6 

Conveyor Stackout S47, Fly Ash Silo S37, SO3 Sorbent Silo S36, Mercury Sorbent Silo S38, 

Pretreatment Soda Ash Silo S44, Pretreatment Hydrated Lime Silo S39, Limestone stackout 

S48 and the vents of Limestone Preparation Building Day Bin Silo S42. These records shall 

be used to demonstrate compliance with the PM2.5 limit in Condition 2.37. These records shall 

be maintained in a format suitable for inspection or submittal to the Division. 

[40 CFR 52.21 and 391-3-1-.02(3)] 

7. Notification, Reporting and Record Keeping Requirements 

Record Keeping Requirements 

7.1 Unless otherwise specified, all records required to be maintained by this Permit shall be 

recorded in a permanent form suitable for inspection and submission to the Division and to 

the EPA. The records shall be retained for at least five (5) years following the date of entry. 

[391-3-1-.02(6)(b)1] 

7.2 The Permittee shall use the hour meters required by Condition No. 5.3.a to determine and 

record the net operating hours for the auxiliary boiler S45, during every calendar month. The 

Permittee shall use these records to determine the total operating hours for the boiler for the 

twelve consecutive month period ending with each calendar month. These records (including 

calculations) shall be maintained as part of the monthly record suitable for inspection or 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 23 of 32 

4911-303-0051-P-01-0 

submittal. A twelve consecutive month total shall be the total for a month in the reporting 

period plus the totals for the previous eleven consecutive months. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

7.3 For each shipment of diesel fuel oil received, as defined in Condition 2.12 and 2.34, the 

Permittee shall obtain from the supplier of the fuel oil, a statement certifying that the oil 

complies with the specifications of ultra low sulfur diesel fuel oil contained in ASTM D975. 

As an alternative to the procedure described above, the Permittee may, for each shipment of 

diesel fuel oil received, obtain a sample for analysis of the sulfur content. The procedures of 

ASTM D4057 shall be used to acquire the sample. Sulfur content shall be determined using 

the procedures of Test Method ASTM D129 or by some other test method approved by the 

US EPA and acceptable to the Division. The Permittee shall keep records of the verification. 

[40 CFR 63 Subpart B; 40 CFR 52.21; 40 CFR 60 Subpart IIII and 391-3-1-.02(6)(b)1] 

7.4 The Permittee shall retain records of all fuel burned in the Coal Fired Boiler S1, at the 

frequency specified below. The records shall be available for inspection or submittal to the 

Division, upon request, and contain the following: 

a. Monthly quantity (tons) of each coal type burned. 

b. Monthly quantity (gallons) of ultra low sulfur diesel fuel oil burned. 

7.5 The Permittee shall determine compliance with the NOx emissions limitations in Condition 

No. 2.13.a and 2.13.r using emissions data acquired by the NOx CEMS. The 30-day rolling 

average and 12-month rolling average shall be determined as follows: 

 [40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The 30-day average shall be the average of all valid hours of NOx emissions data for 

any 30 successive operating days. 

b. After the first 30-day average, a new 30-day rolling average shall be calculated after 

each operating day. 

c. For the purpose of this Permit, an operating day is a 24-hour period between 12:00 

midnight and the following midnight during which any fuel is combusted at any time. It 

is not necessary for the fuel to be combusted continuously for the entire 24-hour period. 

d. A 12-month average shall be the average for any 12 consecutive months. 

These records (including calculations) shall be maintained as part of the monthly record 

suitable for inspection or submittal. 

7.6 The Permittee shall determine compliance with the SO2 emissions limitations in Condition 

No. 2.13.f, g, h and p and with the minimum SO2 removal efficiency in Condition No 2.14 

using emissions data acquired by the SO2 CEMS. The 30-day rolling average (emission rate 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 24 of 32 

4911-303-0051-P-01-0 

and efficiency), 12-month rolling average, 3-hour rolling average and 24-hr rolling average 

shall be determined as follows: 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The 30-day average shall be the average of all valid hours of SO2 emissions data for any 

30 successive operating days. 

b. After the first 30-day average, a new 30-day rolling average shall be calculated after 

each operating day. 

c. For the purpose of this Permit, an operating day is a 24-hour period between 12:00 

midnight and the following midnight during which any fuel is combusted at any time. It 

is not necessary for the fuel to be combusted continuously for the entire 24-hour period. 

d. After the first 3-hour average, a new 3-hour rolling average shall be calculated after 

each operating hour. 

e. After the first 24-hour average, a new 24-hour rolling average shall be calculated after 

each operating hour. 

f. A 12-month average shall be the average for any 12 consecutive months. 

g. The 30-day average removal efficiency shall be the average of all valid hours of SO2

removal efficiency data for any 30 successive operating days. The Permittee shall use 

the inlet and outlet SO2 CEMS data per Condition 5.2.b to determine SO2 removal 

efficiency for each operating hour and for each day of operation. 

These records (including calculations) shall be maintained as part of the monthly record 

suitable for inspection or submittal. 

7.7 The Permittee shall determine compliance with the PM Filterable emissions limitations in 

Condition No. 2.13.d using emissions data acquired by the PM CEMS. The 24-hour rolling 

average shall be determined as follows: 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. After the first 24-hour average, a new 24-hour rolling average shall be calculated after 

each operating hour. 

These records (including calculations) shall be maintained as part of the monthly records 

suitable for inspection or submittal. 

7.8 The Permittee shall determine compliance with the CO emissions limitations in Condition No. 

2.13.b and c using emissions data acquired by the CO CEMS. The 1-hour average and 30-day 

rolling average shall be determined as follows: 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 25 of 32 

4911-303-0051-P-01-0 

a. After the first 1-hour average, a new 1-hour average shall be calculated after each 

operating hour. 

b. The 30-day average shall be the average of all valid hours of CO emissions data for any 

30 successive operating days. 

c. After the first 30-day average, a new 30-day rolling average shall be calculated after 

each operating day. 

d. For the purpose of this Permit, an operating day is a 24-hour period between 12:00 

midnight and the following midnight during which any fuel is combusted at any time. It 

is not necessary for the fuel to be combusted continuously for the entire 24-hour period. 

These records (including calculations) shall be maintained as part of the monthly record 

suitable for inspection or submittal. 

7.9 The Permittee shall determine compliance with the Mercury emissions limitations in 

Condition No. 2.13.m using emissions data acquired by the Mercury CEMS. The 12-month 

rolling average shall be determined as follows: 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The Permittee shall determine and record the emission rate (lb/MW-hr) of Mercury from 

the Coal Fired Boiler S1, while firing coal. The emission rate from the stack shall be 

recorded continuously. 

b. Using the above records the Permittee shall determine the monthly emission rate, in 

lb/MW-hr per month, of mercury from the Coal Fired Boiler S1. 

c. A 12-month average shall be the average for any 12 consecutive months. 

These records (including calculations) shall be maintained as part of the monthly record 

suitable for inspection or submittal. 

7.10 The Permittee shall maintain the following records as they relate to the startup and shutdown 

of the Coal Fired Boiler S1: 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The type of startup initiated, per day; the hours attributed to the startup, and the hours 

attributed to shutdown. If the Coal Fired Boiler was not in operation on any given day, 

the records shall so note. 

b. Identify startup of the pollution control systems – SCR, Wet Scrubber, Fabric Filter 

Baghouse, Sorbent Injection for Sulfuric Acid Mist and Activated Carbon Injection for 

Mercury. 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 26 of 32 

4911-303-0051-P-01-0 

7.11 The Permittee shall maintain files of all measurements, including continuous monitoring 

systems, monitoring devices, and performance testing measurements; all continuous 

monitoring system or monitoring device calibration checks; adjustments and maintenance 

performed on these systems or devices. These files shall be kept in a permanent form suitable 

for inspection and shall be maintained for a period of at least five (5) years following the date 

of such measurements, reports, maintenance and records. 

[391-3-1-.03(2)(c)] 

7.12 The Permittee shall determine and record the heat input rate in MMBtu/hr from the Coal Fired 

Boiler S1, to ensure that the boiler operates under the maximum design heat input rate as 

stated in Condition No. 2.15. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

7.13 The Permittee shall determine and record the gross electrical output in MW-hr for the Power 

Plant. Data shall be recorded on a continuous basis. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

7.14 The Permittee shall maintain records that the drift eliminator from cooling tower (Emission 

Units S2 to S35) operates in a manner that is consistent with Condition No. 2.18. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

7.15 The Permittee shall keep records of the monitoring on Limestone stackout S48 and the vents 

of Limestone Preparation Building S42, in accordance with 40 CFR 60.676(b). 

[40 CFR 52.21, 40 CFR 60 Subpart OOO and 391-3-1-.02(6)(b)1] 

7.16 The Permittee shall keep records of inspections of dust suppression system to control fugitive 

emissions from the Limestone Railcar Unloading Station A5 and from openings (except for 

vents) from Limestone Preparation Building Day Bin Silo S42, according to 40 CFR 

60.676(b). 

[40 CFR 52.21, 40 CFR 60 Subpart OOO and 391-3-1-.02(6)(b)1] 

7.17 The Permittee shall develop and implement a Dust Suppression Plan in accordance with 

Condition 2.22 to suppress fugitive dust from the Coal handling particulate sources (Emission 

Units A4, A6 to A9), the Ash management particulate sources (Emission Units A1 and A3), 

the Gypsum management particulate sources (Emission Unit A2), the Limestone management 

particulate sources (Emission Units A5 and A10) and the Roadway Particulate Sources 

(Emission Units P1 to P21 and U1 to U15). The plan shall be subject to review and approval 

by the Division and shall include records sufficient to show that the plan is followed. In 

particular, any deviations from the plan, or failure to follow plan procedures, shall be noted. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

7.18 The Permittee shall use the hour meters required by Condition No. 5.4 to determine and 

record the net operating hours for the Emergency Diesel Generator EG1 and the Emergency 

Fire Water Pump EP1 during emergency and non-emergency service during every calendar 

month. The Permittee shall use these records to determine the total operating hours for each of 

these engines for the twelve consecutive month period ending with each calendar month. 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 27 of 32 

4911-303-0051-P-01-0 

These records (including calculations) shall be maintained as part of the monthly record 

suitable for inspection or submittal. A twelve consecutive month total shall be the total for a 

month in the reporting period plus the totals for the previous eleven consecutive months. 

[40 CFR 52.21; 40 CFR 60 Subpart IIII and 391-3-1-.02(6)(b)1] 

7.19 The Permittee shall demonstrate compliance with the NSPS Subpart IIII emission limits for 

the Emergency Diesel Generator EG1 and for the Emergency Fire Water Pump EP1, by 

purchasing certified engines. The engines shall be installed and configured according to the 

manufacturer/s specifications. These records shall be maintained in a format suitable for 

inspection or submittal. 

[40 CFR 60.4211(c)] 

Reporting Requirements 

7.20 [Reserved] 

7.21 The Permittee shall furnish the Division written notification as follows: 

[40 CFR 63 Subpart B; 40 CFR 52.21 and 40 CFR 60.7] 

a. A notification of the date of construction of the Coal Fired Boiler S1, Auxiliary Boiler 

S45, and the Coal Handling Particulate Sources (Emission Units A4, A6 to A9, S40, 

S41, S46 and S47), is commenced postmarked no later than 30 days after such date. 

b. A notification of the actual date of initial startup of the Coal Fired Boiler S1, Auxiliary 

Boiler S45, Coal Handling Particulate Sources (Emission Units A4, A6 to A9, S40, S41, 

S46 and S47) and Limestone Management Particulate Sources (Emission Units A5, 

A10, S42 and S48), postmarked within 15 days after such date. For purposes of this 

permit, “startup” shall mean the setting in operation of an affected facility for any 

purpose. 

c. Certification that a final inspection has shown that construction of the Coal Fired Boiler 

S1 has been completed in accordance with the application, plans, specifications and 

supporting documents submitted in support of this permit. The certification shall be 

included with the notification in paragraph (b). 

7.22 In addition to any other reporting requirements of this Permit, the Permittee shall report to the 

Division in writing, within seven (7) days, any deviations from applicable requirements 

associated with any malfunction or breakdown of process, fuel burning, or emission control 

equipment for a period of four hours or more which results in excessive emissions. 

The Permittee shall submit a written report, which shall contain the probable cause of the 

deviation(s), duration of the deviation(s), and any corrective actions or preventive measures 

taken. 

[391-3-1-.02(6)(b)1.(iv)] 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 28 of 32 

4911-303-0051-P-01-0 

7.23 Excess Emissions 

a. Excess emissions resulting from startup, shutdown, malfunction of any source which 

occur though ordinary diligence is employed shall be allowed provided that: 

 [391-3-1-.02(2)(a)7(i)] 

i. The best operational practices to minimize emissions are adhered to; 

ii. All associated air pollution control equipment is operated in a manner consistent 

with good air pollution control practice for minimizing emissions; and 

iii. The duration of excess emissions is minimized. 

b. Excess emissions which are caused entirely or in part by poor maintenance, poor 

operation, or any other equipment or process failure which may reasonably be prevented 

during startup, shutdown or malfunction are prohibited and are violations of this Permit. 

 [391-3-1-.02(2)(a)7(ii)] 

c. The provisions of this condition and Georgia Rule 391-3-1-.02(2)(a)7 shall apply only to 

those sources which are not subject to any requirement under Georgia Rule 391-3-1-

.02(8) – New Source Performance Standards or any requirement of 40 CFR, Part 60, as 

amended concerning New Source Performance Standards. 

 [391-3-1-.02(2)(a)7(iii)] 

7.24 The Permittee shall submit a written report containing excess emissions, exceedances, and/or 

excursions as described in this permit and any monitor malfunctions for each quarterly period 

ending March 31, June 30, September 30, and December 31 of each year. All reports shall be 

postmarked by the 30th day following the end of each reporting period, April 30, July 30, 

October 30, and January 30, respectively. Reporting required by this condition shall begin at 

the end of the quarter in which initial startup is completed. In the event that there have not 

been any excess emissions, exceedances, excursions or malfunctions during a reporting 

period, the report should so state. Otherwise, the contents of each report shall be as specified 

by the Division’s Procedures for Testing and Monitoring Sources of Air Pollutants and shall 

contain the following: 

[391-3-1-.02(6)(b)1] 

a. A summary report of excess emissions, exceedances and excursions, and monitor 

downtime, in accordance with Section 1.5(c) and (d) of the Division’s Procedures for 

Testing and Monitoring Sources of Air Pollutants, including any failure to follow 

required work practice procedures. 

b. Total operating time during each reporting period. 

c. The magnitude of all excess emissions, exceedances and excursions computed in 

accordance with the applicable definitions as determined by the Director, and any 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 29 of 32 

4911-303-0051-P-01-0 

conversion factors used, and the date and time of the commencement and completion of 

each time period of occurrence. 

d. Specific identification of each period of such excess emissions, exceedances, and 

excursions that occur during startups, shutdowns, or malfunctions of the affected 

facility. The nature and cause of any malfunction (if known), the corrective action taken 

or preventive measures adopted. 

e. The date and time identifying each period during which any required monitoring system 

or device was inoperative (including periods of malfunction) except for zero and span 

checks, and the nature of the repairs, adjustments, or replacement. When the monitoring 

system or device has not been inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

f. Certification that, based on information and belief formed after reasonable inquiry, the 

statements and information in the report are true, accurate, and complete. 

7.25 For the purpose of reporting excess emissions, exceedances or excursions in the report 

required in Condition No. 7.24 (and all others in this Condition), the following excess 

emissions, exceedances, and excursions shall be reported: 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. Excess emissions: (means for the purpose of this Condition and Condition No. 7.24, any 

condition that is detected by monitoring or record keeping which is specifically defined, 

or stated to be, excess emissions by an applicable requirement) 

None required to be reported in accordance with Condition No. 7.24. 

b. Exceedances: (means for the purpose of this Condition and Condition No. 7.24, any 

condition that is detected by monitoring or record keeping that provides data in terms of 

an emission limitation or standard and that indicates that emissions (or opacity) do not 

meet the applicable emission limitation or standard consistent with the averaging period 

specified for averaging the results of the monitoring) 

i. Any 30-day rolling average NOx emission rate which exceeds 0.050 lb/MMBtu 

for the Coal Fired Boiler S1, 

ii. Any 1-hour average CO emission rate which exceeds 0.30 lb/MMBtu for the Coal 

Fired Boiler S1, 

iii. Any 30-day rolling average CO emission rate which exceeds 0.10 lb/MMBtu for 

the Coal Fired Boiler S1, 

iv. Any 24-hour rolling average for Filterable PM/PM10 emission rate which exceeds 

0.010 lb/MMBtu for the Coal Fired Boiler S1, 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 30 of 32 

4911-303-0051-P-01-0 

v. Any 12-month rolling average sulfur dioxide emission rate which exceeds 0.052 

lb/MMBtu for the Coal Fired Boiler S1, 

vi. Any 30-day rolling average sulfur dioxide emission rate which exceeds 0.069 

lb/MMBtu for the Coal Fired Boiler S1, 

vii. Any 3-hour rolling average sulfur dioxide emission rate which exceeds 959 lb/hr 

for the Coal Fired Boiler S1, 

viii. Any 24-hour rolling average sulfur dioxide emission rate which exceeds 0.08 

lb/MMBtu for the Coal Fired Boiler S1, 

ix. Any 30-day rolling average of the SO2 removal efficiency of the Wet Limestone 

Scrubber, as calculated per Conditions 5.2.b and 7.6.g, which is less than 97.5 

percent, 

x. Any 12-month rolling average mercury emission rate that exceeds 7.64 x 10-6

lb/MW-hr (while firing sub-bituminous coal) or the computed weighted average as 

per Condition 2.13.m (while firing blend of sub-bituminous and bituminous coal) 

for the Coal Fired Boiler S1, 

xi. Any 12-month rolling average NOx emission rate that exceeds 0.030 lb/MMBtu 

(while firing sub-bituminous coal) or the computed weighted average as per 

Condition 2.13.r (while firing blend of sub-bituminous and bituminous coal) for 

the Coal Fired Boiler S1. This condition becomes effective 6 months after initial 

start-up of Coal Fired Boiler S1, absent approval by the Division for an extension 

of this date. 

xii. Any time ultra low sulfur fuel oil combusted for startup in the Coal Fired Boiler 

S1, Auxiliary Boiler S45, Emergency Generator EG1 and Firewater Pump EP1 

exceeds 0.0015 percent sulfur by weight, 

xiii. Any twelve consecutive month period during which hours of operation of the 

Auxiliary Boiler exceeds 876 hours, 

xiv. Any twelve consecutive month period during which hours of operation of 

Emergency Generator EG1 or Firewater Pump EP1 exceed 500 hours, 

xv. Any hour that the Coal Fired Boiler S1, has a heat input rate that exceeds 8,300 

MMBtu/hr, 

c. Excursions: (means for the purpose of this Condition and Condition No. 7.24, any 

departure from an indicator range or value established for monitoring consistent with 

any averaging period specified for averaging the results of the monitoring). 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 31 of 32 

4911-303-0051-P-01-0 

i. Any exceedance of the PM emissions limits in Condition 2.13 is an excursion for 

opacity, 

ii. Any exceedance of the SO2 emission limits in Condition 2.13 or 2.14 is an 

excursion for HF and HCl, 

 

7.26 The Permittee shall submit a written report containing the following information for each 

quarterly period ending March 31, June 30, September 30, and December 31 of each year. All 

reports shall be postmarked by the 30th day following the end of each reporting period, April 

30, July 30, October 30, and January 30, respectively. Reporting required by this condition 

shall begin at the end of the quarter in which initial startup is completed. 

[40 CFR 52.21 and 391-3-1-.02(6)(b)1] 

a. The 30-day average NOx emission rate in lb/MMBtu from the Coal Fired Boiler S1, for 

each 30-day average period that ends during the quarterly reporting period. 

b. The 30-day average CO emission rate in lb/MMBtu from the Coal Fired Boiler S1, for 

each 30-day average period that ends during the quarterly reporting period. 

c. The maximum 1-hour CO emission rate in lb/MMBtu from the Coal Fired Boiler S1, 

during the quarterly reporting period. 

d. The twelve-month rolling average SO2 emission rate in lb/ MMBtu from the Coal Fired 

Boiler S1 for each month in the quarterly reporting period. 

e. The 30-day average SO2 emission rate in lb/MMBtu from Coal Fired Boiler S1, for each 

30-day average period that ends during the quarterly reporting period. 

f. The maximum 3-hour rolling average SO2 emission rate in lb/MMBtu from the Coal 

Fired Boiler S1, during the quarterly reporting period. 

g. The maximum 24-hour rolling average SO2 emission rate in lb/MMBtu from the Coal 

Fired Boiler S1, during the quarterly reporting period. 

h. The 30-day average removal efficiency of the Wet Limestone Scrubber, for each 30-day 

average period that ends during the quarterly reporting period. 

i. The maximum 24-hour rolling average Filterable PM/PM10 emission rate in lb/MMBtu 

from the Coal Fired Boiler S1, during the quarterly reporting period. 

j. The twelve-month rolling average mercury emission rate in lb/MW-hr from the Coal 

Fired Boiler S1 for each month in the quarterly reporting period. 

k. Fuel oil certifications for ultra low sulfur diesel fuel oil burned for startup in the Coal 

Fired Boiler S1, Auxiliary Boiler S45, Emergency Generator EG1, and Emergency 
State of Georgia 

Department of Natural Resources 

Environmental Protection Division 

Permit No. Page 32 of 32 

4911-303-0051-P-01-0 

Firewater Pump EP1, and a statement signed by a responsible official of the affected 

facility that the Permittee burned only ultra low sulfur diesel fuel oil during the quarter. 

l. The maximum hourly heat input for the Coal Fired Boiler S1, during the reporting 

period. 

m. The twelve-month rolling average NOx emission rate in lb/MMBtu from the Coal Fired 

Boiler S1 for each month in the quarterly reporting period. 

8. Special Conditions 

8.1 At any time that the Division determines that additional control of emissions from the facility 

may reasonably be needed to provide for the continued protection of public health, safety and 

welfare, the Division reserves the right to amend the provisions of this Permit pursuant to the 

Division's authority as established in the Georgia Air Quality Act and the rules adopted 

pursuant to that Act. 

8.2 The Permittee shall calculate and pay an annual Permit fee to the Division. The amount of the 

fee shall be determined each year in accordance with the “Procedures for Calculating Air 

Permit Fees.”