AIR QUALITY PERMIT

Permit No. Effective Date 

4911­099­0033­P­01­0  May 14, 2007

In accordance with the provisions of the Georgia Air Quality Act, O.C.G.A. Section 12­9­1, et 

seq and the Rules, Chapter 391­3­1, adopted pursuant to or in effect under that Act,

Longleaf Energy Associates, LLC

C/o LS Power Development, LLC

Two Tower Center, 11 th Floor

East Brunswick, New Jersey 08816 

Is issued a Permit for the following:  To construct and operate a nominal 1,200 MW coal fired 

generating station. The facility would consist of two coal (PC) fired boilers, a 175 MMBtu/hr

auxiliary boiler, two steam turbines, one  1500  kW emergency generator, one  450  Hp  diesel 

fueled fire  pump, one  distillate fuel oil storage tank, and  cooling towers. The facility will be 

designed to burn Powder River Basin (PRB) coal and/or Central Appalachian coal. In addition,

the facility may burn small quantities of clarifier sludge  produced  at Georgia Pacific’s nearby 

Cedar Springs containerboard mill. Ultra low sulfur distillate fuel oil will be used as the start­up 

fuel for the two PC units and for operation of the auxiliary boiler, emergency equipment.

Facility location:  Longleaf Energy Station 

State Highway 370 

Hilton, Georgia 31723  (Early County)

This Permit is conditioned upon compliance with all provisions of The Georgia Air Quality Act, O.C.G.A. Section 12­9­1, et seq. the Rules, Chapter 391­3­1, adopted or in effect under that Act,

or any other condition of this Permit.

This Permit may be  subject to revocation, suspension, modification or amendment by the 

Director for cause  including  evidence of noncompliance with any of the  above; or for any 

misrepresentation made in the application dated November 22, 2004 [Application No. 15846], additional information listed in Note A, and supporting data entered therein or attached thereto,

or any subsequent submittals or supporting data; or for any alterations affecting the  emissions

from this source.

This Permit is further subject to and conditions upon the terms, conditions, limitations, standards, or schedules contained in or specified on the attached 29 pages, which 29 pages are a part of this

Permit.

____________________________  Director

Environmental Protection Division
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 1 of 29 

4911­099­0030­P­01­0 

NOTE A 

Subsequent Submittals of Application No. 15846 dated November 22, 2004 

Date  Description

November 22, 2004  Original Application Submittal 

March 30, 2005  Modification of HF and HCl Emissions and PSD Preconstruction 

Monitoring Applicability 

April 13, 2005  Docket Information on EPA HF/HCl Removal Memo 

July 12, 2005  Response to EPD letter requesting clarifications to the original 

application 

August 15, 2005 

Longleaf provided answers to the remaining concerns and updated 

BACT determinations for pollutants which were influenced by the 

two different types of coal ­ i.e. SO2, Lead, HF, and H2SO4. February 23, 2006  Updated SO2 BACT limits with justification.

February 28, 2006  Updated BACT analysis for NOx and PM/PM10 to include 

economics analysis for top technologies

March 10, 2006  Longleaf submitted updated BACT analysis for auxiliary boiler.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 2 of 29 

4911­099­0030­P­01­0 

NOTE B

FACIILTY DESCRIPTION

Emission Units Air Pollution Control Devices 

ID No. Description  ID No. Description 

Combustion Sources 

S01  PC­Fired Boiler – 600 MW

LN1 

CR1 

DS1 

F01 

Low NOx Burners/Over­fire Air

Selective Catalytic Reduction 

Dry Scrubber

Fabric Filter Baghouse

S02  PC­Fired Boiler – 600 MW

LN2 

CR2 

DS2 

F02 

Low NOx Burners/Over­fire Air

Selective Catalytic Reduction 

Dry Scrubber

Fabric Filter Baghouse

S03  Auxiliary Boiler – 175 

MMBtu/hr

LN3  Low NOx Burner/Flue Gas 

Recirculation 

Coal Handling Particulate Sources 

S06  Railcar Unloading Station  N/A  Water sprays and partial enclosure

S07  Stackout Conveyor # 1  N/A  Partial enclosure

S08  Stackout Transfer Point #1  N/A  Partial enclosure

S09  Stackout Conveyor #2  N/A  Partial enclosure

S10  Stackout Transfer Point #2  N/A  Telescopic chute

S11  Active Pile #1  N/A  Water Sprays 

S12  Active Pile #2  N/A  Water Sprays 

S13  Active Pile Reclaim N/A  Partial enclosure

S14  Reclaim Conveyor #1  N/A  Partial enclosure
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 3 of 29 

4911­099­0030­P­01­0

Emission Units Air Pollution Control Devices 

ID No. Description  ID No. Description 

S15  Transfer Tower N/A  Partial enclosure and fabric filter

S16  Reclaim Conveyor #2  N/A  Partial enclosure

S17  Tripper Deck  N/A  Partial enclosure and fabric filter

S18  Inactive Pile N/A  Water spray and chemical dust

suppression 

Ash Management Particulate Sources 

S19  Submerged Chain Conveyors  N/A  Partial enclosure and material 

moisture content 

S20  Bottom Ash Transfer Point #1  N/A  Material moisture content 

S21  Bottom Ash Conveyor N/A  Partial enclosure and material 

moisture content 

S22  Bottom Ash Bunker N/A  Partial enclosure and material 

moisture content 

S23  Bottom Ash Transfer Point #2  N/A  Material moisture content 

S24  Bottom Ash Truck  N/A  Material moisture content 

S25  Bottom Ash Transfer Point #3  N/A  Material moisture content 

S26  Fly Ash Silo  N/A  Fabric Filter

S27  Fly Ash Mixing Station  N/A  Fabric Filter

S28  Fly Ash Transfer Point #1  N/A  Material moisture content 

S29  Fly Ash Truck  N/A  Material moisture content 

S30  Fly Ash Transfer Point #2  N/A  Material moisture content 

S31  On­Site Disposal Facility  N/A  Water sprays and chemical 

suppressant
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 4 of 29 

4911­099­0030­P­01­0

Emission Units Air Pollution Control Devices 

ID No. Description  ID No. Description 

Lime Management Particulate Sources 

S35  Lime Railcar Unloading Station  N/A  Partial enclosure and fabric filter

S36  Lime Conveyor N/A  Partial enclosure

S37  Lime Silo  N/A  Partial enclosure and fabric filter

Roadway Particulate Sources 

S38  Unpaved Roadway Travel  N/A  Gravel or chemical dust suppressant 

and water sprays 

S39  Paved Roadway Travel  N/A  Water sprays and/or sweeping 

Cooling Tower Emissions 

S40  Unit 1 Cooling Tower N/A  Drift eliminators 

S41  Unit 2 Cooling Tower N/A  Drift eliminators 

Emergency Diesel Fired Engines 

S42  1500 kW Diesel Generator N/A  N/A 

S43  450 hp Diesel Firewater Pump  N/A  N/A 

Fuel Storage Tanks 

S44  330,000 Gallon Distillate Oil 

Storage Tank  N/A  N/A 

S45  15,000 Gallon Distillate Fuel 

Storage Tank  N/A  N/A 

S46  2,000 Gallon Diesel Fuel 

Storage Tank  N/A  N/A 

S47  500 Gallon Diesel Fuel Storage

Tank  N/A  N/A 

S48  150 Gallon Unleaded Gasoline

Storage Tank  N/A  N/A
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 5 of 29 

4911­099­0030­P­01­0 

1.0  General Requirements

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

to the  extent  practicable 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  of the

source.

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

unit when so directed by the Environmental Protection Division (“Division”). The test

results shall be submitted to the Division within 60 days of the completion of the testing. Any tests shall be performed and conducted using methods and procedures that have been 

previously specified or approved by the Division.

[391­3­1­.02(6)(b)1(i)]

1.3  The Permittee shall provide the Division thirty (30) days (or sixty (60) days for tests 

required by 40 CFR Part 63) 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.

[391­3­1­.02(3)(a)]

1.4  Notwithstanding any other provisions of any applicable rule or regulation or requirement 

of this permit, for the purpose of establishing whether or not a person has violated or is in 

violation of any emissions limitation or standard, nothing in this permit or any Emission 

Limitation or Standard to which it pertains, shall preclude the use, including the exclusive 

use, of any  credible  evidence or information, relevant to whether a source would have

been in compliance with applicable requirements if the appropriate performance or

compliance test or procedure had been performed. [391­3­1­.02(3)(a)]

1.5  The Permittee shall comply with all applicable provisions of National Emission Standard 

for Hazardous Air Pollutants (NESHAP) 40 CFR 61, Subpart E  –  “National Emission 

Standard for Mercury” the  when PC­Fired Boilers, S01  and S02, are firing clarifier

sludge. [40 CFR 61.50]

1.6  The Permittee shall comply with all applicable provisions  of the National Emission 

Standard for Hazardous Air Pollutants (NESHAP) as found in 40 CFR Part 63, in Subpart 

A – “General Provisions”.

[40 CFR 63, Subpart A]

1.7  The Permittee shall comply with all applicable  provisions  of 40  CFR 63, Subpart 

DDDDD  –  “NESHAP for Industrial/Commercial/Institutional Boilers  and Process 

Heaters” for the auxiliary boiler, S03. In the event of any discrepancy between the terms 

of this  Permit  and 40  CFR Part  63, Subpart  DDDDD,  the terms  of 40  CFR Part 63,

Subpart DDDDD shall control.

[40 CFR 63.2231]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 6 of 29 

4911­099­0030­P­01­0

1.8  The Permittee shall comply with all applicable provisions  of the New Source

Performance Standard (NSPS) as found in 40 CFR Part  60, in Subpart  A  –  “General 

Provisions”.

[40 CFR 60, Subpart A]

1.9  The Permittee shall comply with all applicable provisions  of the New Source

Performance Standard (NSPS) as found in 40 CFR Part 60, in Subpart Da – “Standards of

Performance for Electric Utility Steam Generating Units for which Construction is 

Commenced After September 18, 1978” for PC­Fired Boilers, S01 and S02.

[40 CFR 60, Subpart Da]

1.10  The Permittee shall comply with all applicable provisions  of the New Source

Performance Standard (NSPS) as found in 40 CFR Part 60, in Subpart Db – “Standards of

Performance for Industrial­Commercial­Institutional Steam Generating Units” for the 

auxiliary boiler, S03.

[40 CFR 60, Subpart Db]

1.11  The Permittee shall comply with all applicable provisions  of the New Source

Performance Standard (NSPS) as found in 40 CFR Part 60, in Subpart Y – “Standards of

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

equipment and the coal silos.

[40 CFR 60, Subpart Y]

1.12  The Permittee shall comply with all applicable provisions of 40 CFR 63, Subpart ZZZZ –  “National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating 

Internal Combustion Engines” for the emergency  diesel generator, S42  and  emergency 

firewater pump, S43. In the event of any discrepancy between the terms of this Permit 

and 40 CFR 63, Subpart ZZZZ, the terms of 40 CFR 63, Subpart ZZZZ shall control.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 7 of 29 

4911­099­0030­P­01­0 

2.0  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  The Permittee shall commence construction within 18 months of the date of issuance of

this Permit. In the event that construction of any of these units has not commenced in the

time frame specified, and absent  approval by the Division for an extension of the

commencement date, this Permit shall become null and void with respect to that unit and 

all units yet to be constructed. 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  The construction of PC­Fired Boilers  S01  and S02, Auxiliary Boiler S03, Emergency 

Generator S42, Diesel Fire­water pump S43, Coal handling particulate sources (Emission 

Unit  IDs  S06  –  S18), Ash management  particulate sources (Emission Unit  IDs  S19  –  S31), Lime management  particulate sources  (Emission Unit  IDs  S35  –  S37), Cooling 

Towers (Emission Unit IDs S40 and S41), and Fuel Storage Tanks (Emission Unit IDs 

S44  –  S48) shall be completed no later than December 31, 2013. In the event  that 

construction of any of these units is  not  completed by the  date specified, and absent 

approval by the Division for an extension of the completion date, this  Permit  shall

become null and void with respect to that unit and all units yet to be constructed. The

Permit will remain in full force and effect with regard to any units for which construction 

has been completed by the applicable construction deadline.

[40 CFR 52.21(r)(2)]

2.3  The Permittee shall install and operate, as BACT for NOx on each PC­Fired Boiler, S01 

and S02, dry low NOx burners, Over­fire Air and Selective Catalytic Reduction.

[40 CFR 52.21(j)]

2.4  The Permittee shall install and operate, as BACT for CO  and VOC  on each PC­Fired 

Boiler, S01 and S02, good combustion practices. [40 CFR 52.21(j)]

2.5  The Permittee shall install and operate, as BACT for SO2, HF, and H2SO4 on each PC­ Fired Boiler, S01 and S02, a dry scrubber. [40 CFR 52.21(j)]

2.6  The Permittee shall  install and operate, as BACT for PM/PM10 and Lead on each PC­ Fired Boiler, S01 and S02, a fabric filter baghouse. [40 CFR 52.21(j)]

2.7  The Permittee shall install and operate, as BACT for Mercury on each PC­Fired Boiler, S01 and S02, Halogenated Activated Carbon Injection. [40 CFR 52.21(j)]

2.8  The Permittee shall install and operate, as BACT for NOx on Auxiliary Boiler, S03, dry 

low NOx burners and Flue Gas Recirculation (FGR). [40 CFR 52.21(j)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 8 of 29 

4911­099­0030­P­01­0

2.9  The Permittee shall install and operate, as BACT for Fly Ash Silo, S26, and Lime Silo, S37, enclosures and vent filters.

[40 CFR 52.21(j)]

2.10  Except  as provided in Condition No. 2.12 the Permittee shall primarily fire PRB Coal, CAPP Coal, and/or clarifier sludge in PC­Fired Boiler, S01 and S02. Blending of other

sources of bituminous coal and/or pet coke shall be permitted subject to Conditions 2.11,

2.14 and 2.15.

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

2.11  The Permittee shall not  fire any fuel in  PC­Fired Boilers, S01  and S02, that  contains 

greater than 3.0 percent sulfur, by weight.

[391­3­1­.02(2)(g)2]

2.12  The Permittee shall fire only ultra low sulfur diesel fuel, which meets the specifications 

defined in Condition 2.13, in startup in PC­Boiler, S01 and S02, in auxiliary boiler S03,

emergency generator S42 and firewater pump S43 unless ultra low sulfur diesel fuel is 

not commercially available. In that event, the Permittee shall use low sulfur diesel fuel 

which shall not contain more than 0.05 percent sulfur by weight.

[40 CFR 52.21(j); 40 CFR 60.333(b)(subsumed) and 391­3­1­.02(2)(g) (subsumed)]

2.13  Ultra low sulfur diesel (ULSD) fuel oil fired in startup  in PC­Boiler, S01  and S02, in 

auxiliary boiler S03, emergency generator S42 and firewater pump S43 shall not contain 

more than 0.0015 percent sulfur by weight [which is equivalent to 15 ppm as defined in 

40 CFR 80.520­527]. [40 CFR 52.21(j); 391­3­1­.02(2)(g) (subsumed)]

2.14  The Permittee shall not  fire clarifier sludge in PC­Fired Boilers, S01  and S02, that 

contains greater than 1.0 percent of the potential total heat input or 61.4 MMBtu/hr in any 

calendar day.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 9 of 29 

4911­099­0030­P­01­0

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

PC­Fired Boiler, S01 and S02, any gases which 

a. Contain nitrogen oxides  (NOx) in excess  of 0.07  lb/MMBtu  on a 30­day rolling 

average.

[40 CFR 52.21(j); 40 CFR 60.44Da(e)(1) (subsumed)]

b. Contain nitrogen oxides (NOx) in excess  of 0.05 lb/MMBtu on a 12­month rolling 

average. This condition becomes effective 6 months after initial start­up of each PC­ Fired boiler, S01 and S02, absent approval by the Division for an extension of this

date.

[40 CFR 52.21(j); 40 CFR 60.44Da(e)(1) (subsumed)]

c. Contain carbon monoxide  (CO) in excess  of 0.15  lb/MMBtu  on  a 30­day  rolling 

average and 0.30 lb/MMBtu on a 1­hour average.

[40 CFR 52.21(j)]

d. Contain particulate matter (PM)  in excess  of 0.012  lb/MMBtu  for filterable 

particulate matter (PM) on a 3­hour average and 0.030 lb/MMBtu for total particulate 

matter on a 3­hour average.

[40 CFR 52.21(j); 391­3­1­.02(2)(d) (subsumed); 40 CFR 60.42Da(c) (subsumed)]

e. Contain sulfur dioxide in excess  of 0.065  lb/MMBtu on a 30­day rolling average

when the uncontrolled sulfur dioxide emission rate  is  less  than or equal to 1 

lb/MMBtu on a 30­day rolling average.

[40  CFR 52.21(j);  40  CFR 60.43Da(i)(l)(i)  (subsumed);  391­3­1­.02(2)(d)

(subsumed)]

f. Contain sulfur dioxide in excess of 0.08 lb/MMBtu on a 30­day rolling average when 

the uncontrolled sulfur dioxide emission rate is greater than 1 lb/MMBtu but less than 

1.25 lb/MMBtu on a 30­day rolling average.

[40  CFR 52.21(j);  40  CFR 60.43Da(i)(l)(i)  (subsumed);  391­3­1­.02(2)(d)

(subsumed)]

g. Contain sulfur dioxide in excess  of 0.105  lb/MMBtu on a 30­day rolling  average

when the uncontrolled sulfur dioxide emission rate is greater than 1.25 lb/MMBtu but 

less than 1.6 lb/MMBtu on a 30­day rolling average.

[40  CFR 52.21(j);  40  CFR 60.43Da(i)(l)(i)  (subsumed);  391­3­1­.02(2)(d)

(subsumed)]

h. Contain sulfur dioxide in excess of 0.12 lb/MMBtu on a 24­hour average.

[40  CFR 52.21(j);  40  CFR 60.43Da(i)(l)(i)  (subsumed);  391­3­1­.02(2)(d)

(subsumed)]

i. Contain volatile organic  compounds (VOC)  in excess  of 3.6  x  10 ­3lb/MMBtu, as 

methane, on a 3­hour average.

[40 CFR 52.21(j)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 10 of 29 

4911­099­0030­P­01­0

j. Contain lead (Pb) in excess of 1.8 x 10 ­5lb/MMBtu on a 3­hour average.

[40 CFR 52.21(j)]

k. Contain fluorides  (as  HF)  in excess  of 9.5  x  10 ­4lb/MMBtu  on a 3­hour average

while firing PRB coal or 1.4 x 10 ­3lb/MMBtu on a 3­hour average while firing CAPP

Coal or a computed weighted  average based on the proportion of energy output in 

MMBtu input contributed by each coal rank burned during the compliance period and 

its applicable HF emissions limit.

[40 CFR 52.21(j)]

l. Contain sulfuric acid mist (H2SO4) in excess  of 0.005  lb/MMBtu  on a 3­hour

average.

[40 CFR 52.21(j)]

m. Contain mercury (Hg) in excess of 15 x 10 ­6lb/MW­hr on an annual average while 

firing PRB coal or 6 x 10 ­6lb/MW­hr on an annual average while firing CAPP coal, or a computed weighted average based on the proportion of energy output in gross 

MW output contributed by each coal rank burned during the compliance period and 

its applicable Hg emissions limit.

[40 CFR 52.21(j); 40 CFR 60.45Da(a) (subsumed)]

n. Contain mercury from clarifier sludge incineration in both PC­Fired Boilers, S01 and 

S02, in excess of 3.2 kg (7.1 lb) of mercury per 24­hour period.

[40 CFR 61.52(b)]

o. Contain hydrochloric acid (HCl) in excess of 0.0013 lb/MMBtu on a 3­hour average

while firing PRB coal or 0.0083 lb/MMBtu on a 3­hour average while firing CAPP

coal or a computed weighted average based on the proportion of energy output in 

MMBtu input contributed by each coal rank burned during the compliance period and 

its applicable HCl emissions limit.

[Georgia Air Toxic Guideline ­ 391­3­1­.02(2)(a)3]

p. Exhibit greater than 20 percent opacity.

[40  CFR 52.21(j);  and 391­3­1­.02(2)(d) (subsumed);  40  CFR 60.42Da(b)

(subsumed)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 11 of 29 

4911­099­0030­P­01­0

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

Auxiliary Boiler, S03 any gases which 

a. Contain nitrogen oxides (NOx) in excess of 0.1 lb/MMBtu.

[40 CFR 52.21(j)]

b. Contain carbon monoxide (CO) in excess of 0.04 lb/MMBtu.

[40 CFR 52.21(j); 40 CFR 63.7500 (subsumed)]

c. Contain particulate matter (PM) in excess of 0.01 lb/MMBtu for filterable particulate

matter and 0.05 lb/MMBtu for total particulate matter.

[40 CFR 52.21(j); 391­3­1­.02(2)(d) (subsumed); 40 CFR 60.43b(h) (subsumed); 40 

CFR 63.7500 (subsumed)]

d. Contain  volatile organic  compounds  (VOC) in  excess  of 0.003  lb/MMBtu, as 

methane.

[40 CFR 52.21(j)]

e. Contain sulfuric acid mist (H2SO4) in excess of 6 x 10 ­5lb/MMBtu.

[40 CFR 52.21(j)]

f. Exhibit greater than 10 percent opacity.

[40  CFR 52.21(j);  40  CFR 63.7500 and 391­3­1­.02(2)(d) (subsumed);  40  CFR

60.43b(f) (subsumed)]

g. Contain hydrochloric acid (HCl) in excess of 0.0009 lb/MMBtu.

[40 CFR 63.7500]

2.17  The Permittee shall limit each PC­Fired boiler, S01 and S02, to a maximum design heat 

input of 6,139 MMBtu/hr on a one­hour average.

[40 CFR 52.21(j)]

2.18  The Permittee shall limit the hours of operation of Emergency Generator S42 and of Fire

Water Pump  S43 such that  the total hours  of operation of each unit  does  not  equal or

exceed 500 hours or 150 hours respectively during any twelve consecutive months.

[40 CFR 52.21(j)]

2.19  The Permittee shall limit the hours of operation of auxiliary boiler S03 such that the total 

hours  of operation does  not  equal or exceed  500  hours  during any twelve consecutive

months.

[40 CFR 52.21(j)]

2.20  The percent  opacity from coal handling particulate sources (Emission Unit  IDs  S06  –  S18) shall not  equal or exceed 10  percent. [40  CFR 52.21(j);  40  CFR 60.252(c)

(subsumed), 391­2­1­.02(2)(n)2 (subsumed)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 12 of 29 

4911­099­0030­P­01­0

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

becoming airborne from the following operations: 

[391­3­1­.02(2)(n)1]

a. Coal handling particulate sources (Emission Unit IDs S06 – S18)

b. Ash management particulate sources (Emission Unit IDs S19 – S31)

c. Lime management particulate sources (Emission Unit IDs S35 – S37)

d. Roadway Particulate Sources (Emission Unit IDs S38 and S39)

2.22  The percent  opacity from the Ash management particulate sources (Emission Unit IDs 

S19 – S31) shall not equal or exceed 10 percent.

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

2.23  The percent opacity from the Lime management particulate sources (Emission Unit IDs 

S35 – S37) shall not equal or exceed 10 percent.

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

2.24  The Permittee shall install and operate, as BACT for cooling towers, S40 and S41, drift 

eliminators and shall maintain documentation that a 0.001% drift is guaranteed.

[40 CFR 52.21(j)]

3.0  Process and Control Equipment

Not applicable.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 13 of 29 

4911­099­0030­P­01­0 

4.0  Performance Testing

4.1  Performance and compliance 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. The methods for the determination 

of compliance with emission limits listed under Section 2.0 which pertain to the emission 

units listed in Note B are as follows:

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 or 3A 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, for the determination of filterable Particulate

Matter concentration, the sampling time for each run shall be two hours,

g. Method 7  or 7E  for the determination of Nitrogen Oxide concentration from the

auxiliary boiler, S03, the sampling time for each run shall be one hour,

h. Method 8  shall be used for the determination of sulfur acid mist emissions, the 

sampling time for each run shall be one hour,

i. Method 9  and  the  procedures  contained  in  Section  1.3  of the above reference

document shall be used for the determination of opacity,

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

sampling time for each run shall be one hour,

k. Method 19 shall be used for the determination of particulate matter (PM),  carbon 

monoxide, and nitrogen oxides, and sulfur dioxide emission rates,

l. Method 25A shall be used to determine total Hydrocarbons and to calculate Volatile

Organic Compound emissions, the sampling time for each run shall be one hour, m. Method 26A shall be used for the determination of Fluorine and hydrochloric acid 

emission rates from the PC­Fired Boilers, S01 and S02, the sampling time for each 

run shall be one hour,
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 14 of 29 

4911­099­0030­P­01­0

n. Method 29 shall be used for the determination of lead emission rates, while firing 

PRB or CAPP coal, from the PC­Fired Boilers, S01 and S02, the sampling time for

each run shall be one hour,

o. Method 101A for a stack test or 105  for sludge sampling shall be used for the

determination of mercury emissions while firing clarifier sludge unless an alternative

method is approved by EPA, from the PC­Fired Boilers, S01 and S02,

p. Method 202 shall be used for the determination of the condensible portion of total 

particulate matter.

q. Compliance with the Hg limit in Condition 2.15.m. shall be determined according to 

the procedures in 40 CFR 60.50Da(h)(1) through (h)(3) using the CEMS required by 

Condition 5.2.

[40 CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

r. Compliance with the NOx limits in Condition 2.15.a. and 2.15.b. and the SO2 limits

in Condition 2.15.e., 2.15.f., 2.15.g., and 2.15.h. shall be determined using the CEMS

required by Condition 5.2.

[40 CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

s. Compliance with  the CO  limit in Condition 2.15.c. shall be determined  using  the

CEMS required by Condition 5.2.

[40 CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

t. Compliance with the filterable PM  limit in Condition 2.15.d. shall be determined 

using the CEMS required by Condition 5.2.

[40 CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

u. Compliance with the opacity limit in Condition 2.15.p. shall be determined using the

COMS required by Condition 5.2.

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.

[391­3­1­.02(3)(a)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 15 of 29 

4911­099­0030­P­01­0

4.2  Within 60 days after achieving the maximum production rate on each coal type (PRB and 

CAPP) at which each PC­fired boiler, S01 and S02, will be operated, but not later than 

180  days  after the  initial startup  of each  boiler for each coal type, the Permittee shall

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

the results of such performance tests:

a. Performance tests  on each PC­fired boiler, S01  and S02, for volatile organic 

compounds at base load and at 50 percent load to verify compliance with Condition 

No. 2.15.i.

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

b. Performance tests  on each PC­fired boiler, S01  and S02, for particulate emissions 

(PM) to verify compliance with Condition No. 2.15.d.

[40 CFR 52.21, 40 CFR 60.13, 40 CFR 60.42a(c) (subsumed), 391­3­1­.02(6)(b)1.(i)]

c. Performance tests  on each PC­fired boiler, S01  and S02, for lead to verify 

compliance with Condition No. 2.15.j.

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

d. Performance tests on each PC­fired boiler, S01 and S02, for fluoride emissions (as 

HF) while firing PRB coal to verify compliance with Condition No. 2.15.k.

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

e. Performance tests on each PC­fired boiler, S01 and S02, for fluoride emissions (as 

HF) while firing CAPP coal to verify compliance with Condition No. 2.15.k.

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

f. Performance tests  on  each PC­fired boiler, S01  and S02, for sulfuric acid mist to 

verify compliance with Condition No. 2.15.l.

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

g. Performance tests on each PC­fired boiler, S01 and S02, for hydrochloric acid while 

firing PRB coal to verify compliance with Condition No. 2.15.o.

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

h. Performance tests on each PC­fired boiler, S01 and S02, for hydrochloric acid while 

firing CAPP coal to verify compliance with Condition No. 2.15.o.

[40 CFR 52.21 and 391­3­1­.02(6)(b)1.(i)]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 16 of 29 

4911­099­0030­P­01­0

i. Performance test or sludge sampling on each PC­Fired Boilers, S01 and S02, shall be

completed within 90 days of start up for mercury while firing clarifier sludge to very 

compliance with Condition No. 2.15.n, unless an alternative is approved by EPA. If

the facilities emissions exceed 1.6 kg (3.5 lb) per 24­hour period, demonstrated either

by stack sampling  according to §61.53  or sludge sampling according to §61.54  or

another alternative approved by EPA, shall monitor mercury emissions at intervals of

at least once per year by use of Method 105, or an alternative approved by EPA.

4.3  Within  60  days after achieving  the  maximum production rate at  which the auxiliary 

boiler, S03, 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: 

a. Performance tests  on the  auxiliary boiler, S03, for carbon monoxide to verify 

compliance with Condition No. 2.16.b.

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

b. Performance tests  on the auxiliary boiler, S03, for volatile organic  compounds  to 

verify compliance with Condition No. 2.16.d.

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

c. Performance tests  on the auxiliary boiler, S03, for particulate  emissions  (PM)  to 

verify compliance with Condition No. 2.16.c.

[40 CFR 52.21, 391­3­1­.02(6)(b)1.(i)]

d. Performance test on  the  auxiliary boiler, S03, for nitrogen  oxides (NOx) to  verify 

compliance with Condition No. 2.16.a.

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

e. Performance tests  on the auxiliary boiler, S03, for sulfuric acid mist to verify 

compliance with Condition No. 2.16.e.

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

f. Performance test on the auxiliary boiler, S03, for opacity to verify compliance with 

Condition 2.16.f.

g. Performance tests on the auxiliary boiler, S03, or fuel sampling to verify compliance

with Condition 2.16.g.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 17 of 29 

4911­099­0030­P­01­0 

5.0  Monitoring Requirements

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.

[391­3­1­.02(6)(b)1]

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 each PC­fired  boiler stack, S01  and  S02. The

one­hour average nitrogen oxides emissions rates shall also be recorded in pound per

million Btu heat input [40 CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

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

monoxide emissions discharged to the atmosphere from each PC­fired boiler stack, S01 and S02. The one­hour average carbon monoxide emissions rates shall also be

recorded in pound per million Btu heat input. [40 CFR 52.21and 391­3­1­.02(6)(b)1]

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

at both the inlet and outlet of the SO2 control device. The one­hour average sulfur

dioxides  emissions rates shall be recorded in pound per million Btu  heat input [40 

CFR 52.21; 391­3­1­.02(6)(b)1; 40 CFR 60.13]

d. A Continuous  Emissions  Monitoring Systems  (CEMS) to measure and record the

concentration of Hg in the exhaust gases from each PC­fired boiler stack according to 

the requirements in 40  CFR 60.49a(p)(1) through (p)(3). Alternatively, for an 

affected facility that is also subject to the requirements of 40 CFR 75 Subpart I, the

Permittee may install, certify, maintain, operate and quality­assure the data from a Hg 

CEMS according to 40 CFR 75.10 and appendices A and B to 40 CFR 75, in lieu of

following the procedures  in 40  CFR 60.49a(p)(1) through (p)(3). [40  CFR 52.21; 

391­3­1­.02(6)(b)1; 40 CFR 60.13]

e. A Continuous Opacity Monitoring System (COMS) on each PC­fired Boiler stack, S01 and S02.

f. A Continuous  Emissions  Monitoring System (CEMS) for measuring filterable 

particulate matter emissions discharged to the atmosphere from each PC­fired boiler

stack, S01 and S02. The system shall meet the requirements in 40 CFR 60.48a(p)(2)

through (p)(8).
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 18 of 29 

4911­099­0030­P­01­0

g. A continuous  monitoring system for measuring  oxygen  or carbon dioxide  at  each 

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

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.

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

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

the following: auxiliary boiler S03, emergency generator S42, and firewater pump 

S43. Data shall be recorded monthly.

b. The amount of clarifier sludge (in pounds) combusted in each PC­Fired Boiler, S01 

and S02. The data will be recorded once per calendar day of process operation.

c. The heat input to each PC­Fired Boiler, S01 and S02. Data shall be recorded hourly 

using heat input determined in accordance with 40 CFR 75.

6.0  Ambient Monitoring

Not applicable

7.0  Fugitive Emissions

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

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

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 19 of 29 

4911­099­0030­P­01­0 

8.0  Notification, Reporting, and Record Keeping

Record Keeping Requirements

8.1  All records required to be maintained by this  Permit shall be recorded in a permanent 

form suitable for inspection and submission to the Division. The records  shall be

retained for at least five (5) years following the date of entry. [391­3­1­.02(6)(b)1(i)]

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

record the following: [391­3­1­.02(6)(b)1 and 40 CFR 52.21]

a. The net  operating hours  for each  of the following during every calendar month: 

auxiliary boiler S03, emergency generator S42 and firewater pump S43.

b. The total operating hours for each of the following for the twelve consecutive month 

period ending with each calendar month: auxiliary boiler S03, emergency generator

S42, and firewater pump S43.

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.

8.3  The Permittee shall obtain a sample of from each coal shipment for analysis for sulfur

content  (%S), moisture content, ash content, and Gross  Caloric Value (GCV). The

sample  shall be acquired and analyzed using the procedures  of Section 12.5.2.1  in 

Method 19 of the Division's Procedures for Testing and Monitoring Sources of Air

Pollutants.

[391­3­1­.02(6)(b)1(i)]

8.4  The Permittee shall retain records of all fuel burned in the PC­Fired boilers, S01 and S02 

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

submittal to the Division, upon request, and contain the following: 

[391­3­1­.02(6)(b)1(i)]

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

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

c. Quantity (pounds) of clarifier sludge burned daily (24­hour).

d. Monthly quantity (tons) of pet coke burned.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 20 of 29 

4911­099­0030­P­01­0

8.5  The Permittee shall maintain records of representative samples of the coal burned in the

PC­Fired Boilers, S01 and S02. The records shall be available for inspection or submittal 

to the Division, upon request, and contain the following:

[391­3­1­.02(6)(b)1(i)]

a. Percent ash content of coal.

8.6  For each shipment of ULSD fuel oil received, as defined in Condition 2.13, 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 D 975. As 

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

ultra low sulfur diesel fuel oil received, obtain a sample for analysis of the sulfur content.

The procedures of ASTM D 4057 shall be used to acquire the sample. Sulfur content 

shall be determined using the procedures of Test Method ASTM D 129 or by some other

test method approved by the US EPA and acceptable to the Division.

[40 CFR 63.7506 and 391­3­1­.02(6)(b)1(i)]

8.7  The Permittee shall maintain a record of all actions taken in accordance with Condition 

2.21 to suppress fugitive dust from the Coal handling particulate sources (Emission Unit 

IDs S06 – S18), the Ash management particulate sources (Emission Unit IDs S19 – S31),

the Lime management  particulate sources  (Emission  Unit  IDs  S35  –  S37), and the

Roadway Particulate Sources  (Emission Unit  IDs  S38  and S39). Such records  shall

include the date and time of occurrence and a description of the actions taken.

[391­3­1­.02(6)(b)1(i)]

8.8  The Permittee shall determine  compliance with the NOx  emissions  limitations  in 

Condition No. 2.15.a and b using emissions data acquired by the NOx CEMS. The 30­

day rolling average and 12­month rolling average shall be determined as follows: [391­

3­1­.02(6)(b)1(i)]

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

any 30 successive operating days.

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

each operating day.

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

period  plus  the totals  for the  previous  11 consecutive months. These records 

(including calculations) shall be maintained as part of the monthly record suitable for

inspection or submittal.

d. For the purpose of this Permit, an operating day is a 24­hour 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 24­hour

period.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 21 of 29 

4911­099­0030­P­01­0

8.9  The Permittee shall determine compliance with the SO2 emissions  limitations  in 

Condition No. 2.15.e, f, and g using emissions data acquired by the SO2 CEMS. The 30­

day rolling average shall be determined as follows: [391­3­1­.02(6)(b)1(i)]

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

any 30 successive operating days.

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

each operating day.

c. For the purpose of this Permit, an operating day is a 24­hour 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 24­hour

period.

8.10  The Permittee shall determine compliance with the CO  emissions  limitations  in 

Condition No. 2.15.c using emissions  data acquired  by the  CO  CEMS. The 30­day 

rolling average shall be determined as follows: [391­3­1­.02(6)(b)1(i)]

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

any 30 successive operating days.

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

each operating day.

c. For the purpose of this Permit, an operating day is a 24­hour 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 24­hour

period 

8.11  The Permittee shall determine compliance with the PM filterable emissions limitations in 

Condition No. 2.15.d using emissions  data acquired  by the  PM  CEMS. The 3­hour

rolling average shall be determined as follows: [391­3­1­.02(6)(b)1(i)]

a. The 3­hour average shall be the  average of all valid hours  of PM  filterable 

emissions data for any 3 successive operating hours.

b. After the first 3­hour average, a new 3­hour average shall be calculated after each 

3­hour block.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 22 of 29 

4911­099­0030­P­01­0

8.12  The Permittee shall determine compliance with the mercury emissions  limitations  in 

Condition No. 2.15.m using emissions data acquired by the mercury CEMS. The annual 

average shall be determined as follows: [40 CFR 52.21; 391­3­1­.02(6)(b)1.(i)]

a. The Permittee shall determine and record the emission rate (lb/MW­hr) of

mercury from each PC­Fired Boiler while firing coal. The emission rate from 

each stack, as specified in Condition No. 2.15, shall be recorded continuously.

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

in lb/MW­hr per month, of mercury from each PC­Fired Boiler. These records 

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

for inspection or submittal.

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

period plus  the totals for the  previous  11  consecutive  months. These records 

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

for inspection or submittal.

8.13  The Permittee shall determine  and record the emission rate (lb  per 24­hour period) of

mercury from each PC­Fired Boiler, S01 and S02, while firing clarifier sludge, using the

stack testing or sampling required by Condition No. 4.2.k and the records required by 

Condition No. 8.4.c. [40 CFR 61.55]

8.14  The Permittee shall use the records required by Condition No. 8.13 to determine the 24­

hour total of mercury emissions (in lbs) from each PC­Fired Boiler, for each month while

firing clarifier sludge. For the  purpose of this  Permit, an operating  day is  a 24­hour

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 24­hour period.

[40 CFR 61.55]

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

shutdown of each PC­Fired Boiler, S01 and S02: 

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

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

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

the records shall so note.

b. Identify startup  of the  pollution control systems  –  SCR, Dry Scrubber, and Fabric

Filter Baghouse
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 23 of 29 

4911­099­0030­P­01­0

8.16  The Permittee shall verify and document that each shipment of ultra low sulfur diesel fuel 

oil (ULSD) received for combustion in the auxiliary boiler, emergency diesel generator, and the firewater pump, S03, S42, and S43, complies with the requirements of Condition 

2.12 of the Permit by either of the following means: 

[40 CFR 63.7506 and 391­3­1­.02(6)(b)1(i)]

a. Fuel oil receipts obtained from the fuel supplier certifying that the oil is diesel fuel 

oil and contains less than or equal to 0.0015 percent sulfur, by weight.

b. Analysis of the fuel oil conducted by methods of sampling and analysis which have

been specified or approved by the Division which demonstrates that the diesel fuel 

oil contains less than or equal to 0.0015 percent sulfur, by weight.

8.17  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.

[391­3­1­.03(2)(c)]

8.18  The Permittee shall develop and implement a Dust Suppression Plan sufficient to assure

that the provisions of Condition Nos. 2.20, 2.21, 2.22, and 2.23 are met. 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.

[391­3­1­.02(6)(b)1]

8.19  The Permittee shall determine and record the heat rate from each PC­Fired Boiler, S01 

and S02 to ensure that each boiler operates under the maximum design heat input rate as 

stated in Condition No. 2.17.

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

8.20  The Permittee shall maintain documentation that the drift eliminators from each cooling 

tower, S40 and S41 operate in a manner that is consistent with Condition No. 2.24.

[391­3­1­.02(6)(b)1(i) and 40 CFR 52.21]
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 24 of 29 

4911­099­0030­P­01­0

Reporting Requirements

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

[40 CFR 52.21; 40 CFR 60.7; 40 CFR 61.09]

a. A notification of the date of construction of each PC­Fired Boiler, S01  and S02,

auxiliary boiler, S03, and the Coal Handling Particulate Sources, S06  –  S18, is 

commenced postmarked no later than 30 days after such date.

b. A notification of the actual date of initial startup of each PC­Fired Boiler, S01 and 

S02, auxiliary boiler, S03, and the Coal Handling Particulate Sources, S06  –  S18,

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 each PC­Fired 

Boiler, S01 and S02, 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).

d. A notification of the testing or sludge sampling completion as required by 40 CFR

61.53 and 61.54 within 90 days of startup while firing clarifier sludge in each PC­ Fired Boiler, S01 and S02.

8.22  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.

[391­3­1­.02(6)(b)1.(iv)]

8.23  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:

[391­3­1­.02(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.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 25 of 29 

4911­099­0030­P­01­0

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.

[391­3­1­.02(2)(a)7(ii)]

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

only to those sources which are not subject to any requirement under Georgia Rule 

391­3­1­.02(8) – New Source Performance Standards or any requirement of 40 CFR, Part 60, as amended concerning New Source Performance Standards.

[391­3­1­.02(2)(a)7(iii)]

8.24  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 30 th 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 even 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: 

[391­3­1­.02(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 above referenced 

document, 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 

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.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 26 of 29 

4911­099­0030­P­01­0

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

required in Condition No. 8.24, the following excess  emissions, exceedances, and 

excursions shall be reported: 

[40 CFR 52.21 and 391­3­1­.02(6)(b)1]

a. Excess emissions: (means for the purpose of this Condition and Condition No. 8.24,

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. 8.24.

b. Exceedances: (means for the purpose of this Condition and Condition No. 8.24, 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 30­day rolling average NOx  emission rate which exceeds  0.07 

lb/MMBtu for each PC­Fired Boiler, S01 and S02,

ii. Any 12­month  rolling average NOx  emission rate  which exceeds 0.05 

lb/MMBtu for each PC­Fired Boiler, S01  and S02, this  condition becomes 

effective 6 months after initial start­up of each PC­Fired boiler, S01 and S02,

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

iii. Any 1­hour average CO  emission rate which exceeds  0.30  lb/MMBtu  for

each PC­Fired Boiler, S01 and S02,

iv. And 30­day rolling average CO emission rate which exceeds 0.15 lb/MMBtu 

for each PC­Fired Boiler, S01 and S02,

v. Any 3­hour block average for filterable PM  emission rate which exceeds 

0.012 lb/MMBtu for each PC­Fired Boiler, S01 and S02,

vi. Any 24­hour average sulfur dioxide emission rate  which exceeds 0.12 

lb/MMBtu for each PC­Fired Boiler, S01 and S02,

vii. Any 30­day rolling average sulfur dioxide emission rate exceeds  0.065 

lb/MMBtu when the uncontrolled sulfur dioxide emission rate is less than or

equal to 1 lb/MMBtu on a 30­day rolling average for each PC­Fired Boiler, S01 and S02,

viii. Any 30­day rolling average sulfur dioxide  emission rate exceeds  0.08 

lb/MMBtu when the uncontrolled sulfur dioxide emission rate is greater than 

1  lb/MMBtu  but  less  than 1.25  lb/MMBtu  on a 30­day rolling average for

each PC­Fired Boiler, S01 and S02,
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 27 of 29 

4911­099­0030­P­01­0

ix. Any 30­day rolling average sulfur dioxide emission rate exceeds  0.105 

lb/MMBtu when the uncontrolled sulfur dioxide emission rate is greater than 

1.25 lb/MMBtu but less than 1.6 lb/MMBtu on a 30­day rolling average for

each PC­Fired Boiler, S01 and S02,

x. Any annual average mercury emission rate that exceeds 15 x 10 ­6lb/MW­hr

while firing PRB coal for each PC­Fired Boiler, S01 and S02,

xi. Any annual average mercury emission rate that  exceeds 6 x 10 ­6lb/MW­hr

while firing CAPP coal for each PC­Fired Boiler, S01 and S02,

xii. Any 24­hour average mercury emissions rate while firing clarifier sludge that 

exceeds 7.1 lb.

xiii. Any six­minute period during which the average opacity, as measured by a

continuous  opacity monitoring system for either PC­Fired boiler, S01 and 

S02, exceeds 20 percent.

xiv. Any time fuel fired in any PC­Fired Boiler, S01 and S02, has a sulfur content 

which exceeds 3.0 percent sulfur, by weight.

xv. Any time ultra low sulfur fuel oil combusted for startup in PC­Fired boilers,

S01  and S02, in  auxiliary boiler, S03, in emergency generator S42  and 

firewater pump S43 exceeds 0.0015 percent sulfur by weight.

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

auxiliary boiler exceeds 500 hours.

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

emergency generator S42 or firewater pump S43 exceed 500 and 150 hours 

respectively.

xviii. Any hour that either PC­Fired boiler, S01 and S02, has a heat input rate that 

exceeds 6,139 MMBtu/hr.

xix. Any calendar day that clarifier sludge combustion in either PC­Fired boiler, S01 and S02, exceeds 1.0 percent of the total heat input rate to the boiler, or

61.4 MMBtu/hr.

c. Excursions: (means for the purpose of this Condition and Condition No. 8.24, any 

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

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

i. None required to be reported in accordance with Condition 8.24.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 28 of 29 

4911­099­0030­P­01­0

8.26  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 30 th 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, 40 CFR 63.7506, and 391­3­1­.02(6)(b)1]

a. The twelve consecutive month total hours  of operation of auxiliary boiler, S03,

emergency generator S42, and  firewater pump S43, each, for each  month in the

quarterly reporting period. 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.

b. The annual mercury emission rate in lb/MW­hr from each PC­Fired Boiler, S01 and 

S02, along with the corresponding weighted average limit determined in accordance

with Condition 2.15.m.

c. The 30­day average NOx  emission lb/MMBtu from PC­fired boilers, S01 and S02,

for each 30­day average period that ends during the reporting period.

d. The 12­month rolling average NOx  emission lb/MMBtu from PC­fired boilers, S01 

and S02, for each 11­month average period that ends during the reporting period.

e. The 30­day average SO2 emission lb/MMBtu from PC­fired boilers, S01 and S02, for

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

f. The coal sampling to determine sulfur content, moisture content, and Gross Caloric 

Value as required by condition 8.3. Monthly records on the tons of coal burned in 

Condition 8.4 and the percent ash content as required in Condition 8.5.

g. ULSD fuel oil certifications for ultra low sulfur diesel fuel oil burned for startup in 

each PC­Fired Boiler, S01  and S02, in auxiliary boiler S03, Diesel Emergency 

Generator S42, and Emergency Firewater Pump S43, and  a statement signed  by a

responsible  official  of the affected  facility that  the  records  of fuel supplier

certifications submitted represent all of the ULSD fuel oil was not burned during the

quarter, the report should state that no ULSD fuel oil was burned during the quarter.

h. The 24­hour total of mercury emissions (in lbs) from each PC­Fired Boiler, S01 and 

S02, for each 24­hour period while firing clarifier sludge.

i. The maximum hourly heat input for each PC­Fired Boiler, S01 and S02 during the

reporting period.
STATE OF GEORGIA 

DEPARTMENT OF NATURAL RESOURCES 

ENVIRONMENTAL PROTECTION DIVISION 

Permit No. Page 29 of 29 

4911­099­0030­P­01­0 

9.0  Modifications

9.1  Prior to any source commencing a modification as  defined in Georgia Rule 391­3­1­

.01(pp), which may result in air pollution and not  exempted by Georgia Rule 391­3­1­

.03(6), the Permittee shall submit a Permit application to the Division. The application 

shall be submitted sufficiently in advance of any critical data involved to allow adequate

time for review, discussion, or revision of plans, if necessary. Such application shall

include, but not be limited to, information describing the precise nature of the change, modifications to any emission control system, production capacity of the plant before and 

after the change, and the anticipated completion date of the change. The application shall

be in the  form of a Georgia Air Quality Permit  application to construct  or modify 

(otherwise known as a SIP application) and shall be submitted on forms supplied by the

Division, unless otherwise notified by the Division.

10.0  Special Conditions

10.1  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.

10.2  The Permittee shall submit an Initial Title V permit application within one year of initial 

startup of the plant.

10.3  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.”