Part 70 Operating Permit

Permit Number: 4911-207-0008-V-03-0 Effective Date: May 8, 2012 

Facility Name: Scherer Steam-Electric Generating Plant 

 

Facility Address: 10986 Highway 87 

 Juliette, GA 31046, Monroe County 

Mailing Address: 241 Ralph McGill Blvd. NE, Bin 10221 

 Atlanta, GA 30308-3374 

Parent/Holding 

Company:

Southern Company/Georgia Power 

Facility AIRS Number: 04-13-207-00008

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

Georgia Rules for Air Quality Control, Chapter 391-3-1, adopted pursuant to and in effect under the Act, 

the Permittee described above is issued a Part 70 Permit for:

The operation of an electric utility plant including four steam electric generating units.

This Permit is conditioned upon compliance with all provisions of The Georgia Air Quality Act, O.C.G.A. 

Section 12-9-1, et seq, the Rules, Chapter 391-3-1, adopted and in effect under that Act, or any other 

condition of this Permit. Unless modified or revoked, this Permit expires five years after the effective 

date indicated above.

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, for any misrepresentation made in 

Title V Application No. TV-19764 signed on June 25, 2010, any other applications upon which this Permit 

is based, supporting data entered therein or attached thereto, or any subsequent submittal of supporting 

data, or for any alterations affecting the emissions from this source.

This Permit is further subject to and conditioned upon the terms, conditions, limitations, standards, or 

schedules contained in or specified on the attached 65 pages.

 [Signed] 

Director

Environmental Protection Division
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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Table of Contents 

PART 1.0 FACILITY DESCRIPTION .............................................................................................................1

1.1 Site Determination ...............................................................................................................................1

1.2 Previous and/or Other Names ..............................................................................................................1

1.3 Overall Facility Process Description....................................................................................................1

PART 2.0 REQUIREMENTS PERTAINING TO THE ENTIRE FACILITY .............................................2

2.1 Facility Wide Emission Caps and Operating Limits............................................................................2

2.2 Facility Wide Federal Rule Standards..................................................................................................2

2.3 Facility Wide SIP Rule Standards........................................................................................................2

2.4 Facility Wide Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission 

Cap or Operating Limit........................................................................................................................2

PART 3.0 REQUIREMENTS FOR EMISSION UNITS .................................................................................3

3.1 Emission Units .....................................................................................................................................3

3.2 Equipment Emission Caps and Operating Limits ................................................................................4

3.3 Equipment Federal Rule Standards......................................................................................................5

3.4 Equipment SIP Rule Standards ............................................................................................................7

3.5 Equipment Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission Cap 

or Operating Limit .............................................................................................................................13

PART 4.0 REQUIREMENTS FOR TESTING...............................................................................................14

4.1 General Testing Requirements...........................................................................................................14

4.2 Specific Testing Requirements ..........................................................................................................15

PART 5.0 REQUIREMENTS FOR MONITORING (Related to Data Collection) ....................................17

5.1 General Monitoring Requirements.....................................................................................................17

5.2 Specific Monitoring Requirements ....................................................................................................17

PART 6.0 RECORD KEEPING AND REPORTING REQUIREMENTS ..................................................28

6.1 General Record Keeping and Reporting Requirements .....................................................................28

6.2 Specific Record Keeping and Reporting Requirements.....................................................................32

PART 7.0 OTHER SPECIFIC REQUIREMENTS........................................................................................41

7.1 Operational Flexibility .......................................................................................................................41

7.2 Off-Permit Changes ...........................................................................................................................41

7.3 Alternative Requirements...................................................................................................................42

7.4 Insignificant Activities.......................................................................................................................42

7.5 Temporary Sources ............................................................................................................................42

7.6 Short-term Activities..........................................................................................................................42

7.7 Compliance Schedule/Progress Reports ............................................................................................42

7.8 Emissions Trading..............................................................................................................................42

7.9 Acid Rain Requirements ....................................................................................................................43

7.10 Prevention of Accidental Releases (Section 112(r) of the 1990 CAAA)...........................................48

7.11 Stratospheric Ozone Protection Requirements (Title VI of the CAAA of 1990) ..............................49

7.12 Revocation of Existing Permits and Amendments.............................................................................50

7.13 Pollution Prevention...........................................................................................................................50

7.14 Specific Conditions ............................................................................................................................50

7.15 Clean Air Interstate Rule (CAIR) Requirements ...............................................................................50

PART 8.0 GENERAL PROVISIONS..............................................................................................................52

8.1 Terms and References........................................................................................................................52

8.2 EPA Authorities .................................................................................................................................52

8.3 Duty to Comply..................................................................................................................................52
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

ii 

8.4 Fee Assessment and Payment ............................................................................................................53

8.5 Permit Renewal and Expiration .........................................................................................................53

8.6 Transfer of Ownership or Operation..................................................................................................53

8.7 Property Rights...................................................................................................................................53

8.8 Submissions........................................................................................................................................54

8.9 Duty to Provide Information ..............................................................................................................54

8.10 Modifications .....................................................................................................................................55

8.11 Permit Revision, Revocation, Reopening and Termination...............................................................55

8.12 Severability ........................................................................................................................................56

8.13 Excess Emissions Due to an Emergency ...........................................................................................56

8.14 Compliance Requirements .................................................................................................................57

8.15 Circumvention....................................................................................................................................59

8.16 Permit Shield......................................................................................................................................60

8.17 Operational Practices .........................................................................................................................60

8.18 Visible Emissions...............................................................................................................................60

8.19 Fuel-burning Equipment ....................................................................................................................60

8.20 Sulfur Dioxide....................................................................................................................................61

8.21 Particulate Emissions .........................................................................................................................61

8.22 Fugitive Dust......................................................................................................................................62

8.23 Solvent Metal Cleaning......................................................................................................................62

8.24 Incinerators.........................................................................................................................................63

8.25 Volatile Organic Liquid Handling and Storage .................................................................................64

8.26 Use of Any Credible Evidence or Information ..................................................................................64

8.27 Diesel-Fired Internal Combustion Engines........................................................................................64

Attachments ..............................................................................................................................................................65

A. List of Standard Abbreviations and List of Permit Specific Abbreviations 

B. Insignificant Activities Checklist, Insignificant Activities Based on Emission Levels and Generic 

Emission Groups 

C. List of References 

D. U.S. EPA Acid Rain Program Permit Application for Phase II NOX Averaging Plan 

E. CAIR Permit Application for SO2 and NOX Annual Trading Programs 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 1 of 65 

PART 1.0 FACILITY DESCRIPTION 

1.1 Site Determination 

There are no other facilities which could possibly be contiguous or adjacent and under common 

control.

1.2 Previous and/or Other Names 

This facility is commonly known as Plant Scherer. No other names have been identified.

1.3 Overall Facility Process Description 

Plant Scherer burns fossil fuel to generate electricity. This facility includes four steam electric 

generating units which primarily burn coal. Wet limestone Flue Gas Desulfurization (FGD) 

scrubbers are being installed on Steam Generating Units SG01, SG02, and SG04. An FGD scrubber 

is currently installed on Steam Generating Unit SG03. An 870-foot wet stack for SG01 and SG02, 

with separate liners for each unit is being installed. An 847-foot stack for SG03 and SG04 with 

separate liners for each unit is currently installed. When the FGD scrubbers are operational, during 

normal operation the units will exhaust through the wet stacks. There are some operations when it 

will be necessary to bypass the scrubbers. In these cases the units will exhaust through one of the 

two existing 1000-foot stacks. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 2 of 65 

PART 2.0 REQUIREMENTS PERTAINING TO THE ENTIRE FACILITY 

2.1 Facility Wide Emission Caps and Operating Limits 

None applicable. 

2.2 Facility Wide Federal Rule Standards 

None applicable 

2.3 Facility Wide SIP Rule Standards 

None applicable. 

2.4 Facility Wide Standards Not Covered by a Federal or SIP Rule and Not Instituted as an 

Emission Cap or Operating Limit 

None applicable.
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 3 of 65 

PART 3.0 REQUIREMENTS FOR EMISSION UNITS 

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. 

3.1 Emission Units 

Emission Units Specific Limitations/Requirements Air Pollution Control Devices 

ID No. Description Applicable 

Requirements/Standards 

Corresponding Permit 

Conditions ID No. Description 

SG01 Steam Generator Unit 1 391-3-1-.02(2)(b), (d), (g), 

(jjj), (sss), (uuu) 

40 CFR 60 Subpart A, 

40 CFR 60 Subpart D, 

Acid Rain and CAIR 

40 CFR 63 Subpart A 

40 CFR 63 Subpart UUUUU 

3.2.1, 3.2.2, 3.2.4, 3.3.1 

to 3.3.5, 3.3.8, 3.4.6, 

3.4.10, 3.4.11, 3.4.13, 

3.4.14, 3.4.18, 3.4.19, 

4.2.1, 4.2.4, 5.2.1 to 

5.2.6, 5.2.10 to 5.2.24, 

6.1.7, 6.2.1, 6.2.2, 6.2.7 

to 6.2.10, 6.2.13 to 

6.2.22, 7.9.7, 7.15.2 

SCR1 

EP01 

BH01 

FGD1 

Selective Catalytic Reduction 

ESP 

Baghouse with PAC 

Flue Gas Desulfurization 

SG02 Steam Generator Unit 2 391-3-1-.02(2)(b), (d), (g), 

(jjj), (sss), (uuu) 

40 CFR 60 Subpart A, 

40 CFR 60 Subpart D, 

Acid Rain and CAIR 

40 CFR 63 Subpart A 

40 CFR 63 Subpart UUUUU 

3.2.1, 3.2.2, 3.2.4, 3.3.1 

to 3.3.5, 3.3.8, 3.4.7, 

3.4.10, 3.4.11, 3.4.13, 

3.4.14, 3.4.17, 3.4.19, 

4.2.1, 4.2.4, 5.2.1 to 

5.2.5, 5.2.7, 5.2.10 to 

5.2.24, 6.1.7, 6.2.1, 

6.2.2, 6.2.7 to 6.2.10, 

6.2.13 to 6.2.22, 7.9.7, 

7.15.2 

SCR2 

EP02 

BH02 

FGD2 

Selective Catalytic Reduction 

ESP 

Baghouse with PAC 

Flue Gas Desulfurization 

SG03 Steam Generator Unit 3 391-3-1-.02(2)(b), (d), (g), 

(jjj), (sss), (uuu) 

40 CFR 60 Subpart A, 

40 CFR 60 Subpart D, 

Acid Rain and CAIR 

40 CFR 63 Subpart A 

40 CFR 63 Subpart UUUUU 

3.2.1, 3.2.2, 3.2.4, 3.3.1 

to 3.3.5, 3.3.8, 3.4.8, 

3.4.10, 3.4.11, 3.4.13 to 

3.4.15, 3.4.19, 4.2.1, 

4.2.4, 5.2.1 to 5.2.5, 

5.2.8, 5.2.10 to 5.2.24, 

6.1.7, 6.2.1, 6.2.2, 6.2.7 

to 6.2.10, 6.2.13 to 

6.2.22, 7.9.7, 7.15.2 

SCR3 

EP03 

BH03 

FGD3 

Selective Catalytic Reduction 

ESP 

Baghouse with PAC 

Flue Gas Desulfurization 

SG04 Steam Generator Unit 4 391-3-1-.02(2)(b), (d), (g), 

(jjj), (sss), (uuu) 

40 CFR 60 Subpart A, 

40 CFR 60 Subpart D, 

Acid Rain and CAIR 

40 CFR 63 Subpart A 

40 CFR 63 Subpart UUUUU 

3.2.1, 3.2.2, 3.2.4, 3.3.1 to 

3.3.5, 3.3.8, 3.4.9, 3.4.10, 

3.4.11, 3.4.13, 3.4.14, 

3.4.16, 3.4.19, 4.2.1, 4.2.4, 

5.2.1 to 5.2.5, 5.2.9 to 

5.2.24, 6.1.7, 6.2.1, 6.2.2, 

6.2.7 to 6.2.10, 6.2.13 to 

6.2.22, 7.9.7, 7.15.2 

SCR4 

EP04 

BH04 

FGD4 

Selective Catalytic Reduction 

ESP 

Baghouse with PAC 

Flue Gas Desulfurization 

SB01 Start-up Boiler Unit 1 391-3-1-.02(2)(d) and (g) 3.2.3, 3.4.1, 3.4.2, 3.4.3, 

6.1.7 

none n/a 

SB02 Start-up Boiler Unit 2 391-3-1-.02(2)(d) and (g) See SB01 none n/a 

CHS Coal Handling System 40 CFR 60 Subpart A, 

40 CFR 60 Subpart Y, 

391-3-1-.02(2)(n) 

3.3.1, 3.3.6, 3.4.4, 6.2.5 none n/a 

AHS Ash Handling System 391-3-1-.02(2)(n) 3.4.4, 3.4.5, 3.4.6, 6.2.6 none n/a 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 4 of 65 

Emission Units Specific Limitations/Requirements Air Pollution Control Devices 

ID No. Description Applicable 

Requirements/Standards 

Corresponding Permit 

Conditions ID No. Description 

MHS Materials Handling 

System 

391-3-1-02(2)(e) 

391-3-1-.02(2)(n) 

40 CFR 60 Subpart A 

40 CFR 60 Subpart OOO 

3.3.1, 3.3.7, 3.4.4, 3.4.5, 

3.4.12, 4.2.3, 5.2.17, 

6.1.7, 6.2.13 

LSBA

LSBB 

Limestone Silo Baghouse A 

Limestone Silo Baghouse B 

* Generally applicable requirements contained in this permit may also apply to emission units listed above. The lists of applicable 

requirements/standards and corresponding permit conditions are intended as a compliance tool and may not be definitive. 

3.2 Equipment Emission Caps and Operating Limits 

3.2.1 The Permittee shall not fire any fuel other than coal in the Plant Scherer steam generating 

units (Emission Unit IDs SG01, SG02, SG03, and SG04) except for the following: 

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

a. No. 2 fuel oil, biodiesel, or biodiesel blends may be burned for start-up, shutdown, to 

assist in achieving peak load, and flame stabilization. 

b. Sawdust may be blended and fired with the coal. 

c. Biomass may be blended and fired with the coal. Biomass, as used in this permit, 

shall include, but not be limited to paper, vegetative matter, or wood chips. Biomass 

shall not include sawdust (sawdust is covered by 3.2.1b.) or municipal solid waste 

except as may be specifically listed above. 

d. Used oil, as indicated in Condition 3.2.2, may be burned. 

e. Coal-derived synthetic fuel, manufactured using a binder with mercury of content less 

than or equal to 0.2 ppm on a dry basis and the binder constitutes approximately 2.5% 

by weight or less of the coal-derived synthetic fuel shall be considered coal for the 

purpose of this permit.

State Only Enforceable Condition. 

3.2.2 The Permittee shall not burn used oil in any steam generating unit (Emission Unit IDs 

SG01, SG02, SG03, or SG04) during periods of startup or shutdown. For the purposes of 

this permit, startup shall be defined as the period lasting from the time the first oil fire is 

established in the furnace until the time that mill/burner performance and secondary air 

temperature are adequate to maintain an exit gas temperature above the sulfuric acid dew 

point. For the purpose of this permit, the term shutdown means the cessation of the 

operation of a source or facility for any purpose. 

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

3.2.3 The Permittee shall not fire any fuel other than #2 fuel oil, biodiesel, or biodiesel blends in 

the start-up boilers (Emission Unit IDs SB01 or SB02). 

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

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 5 of 65 

NOX Emission Limits for the 7-Plant Plan 

3.2.4 The Permittee shall not discharge, or cause the discharge, into the atmosphere NOX

emissions, including emissions occurring during startup and shutdown, from the combined 

operations of all affected units (Emission Unit IDs SG01, SG02, SG03, SG04 at Plant 

Bowen (AFS No. 015-00011); SG01, SG02, SG03, SG04 at Plant Branch (AFS No. 237-

00008); SG01, SG02, SG03, SG04 at Plant Hammond (AFS No. 115-00003); SGM1, 

SGM2 at Plant McDonough (AFS No. 067-00003); SG01, SG02, SG03, SG04 at Plant 

Scherer (AFS No. 207-00008); SG01, SG02 at Plant Wansley (AFS No. 149-00001); and 

SG01, SG02, SG03, SG04, SG05, SG06, SG07 at Plant Yates (AFS No. 077-00001)) in 

excess of 32,335.8 tons during the ozone season. For purposes of this permit, the ozone 

season shall be defined as May 1 through September 30. 

[391-3-1-.03(8)(c)1 and 391-3-1-.03(8)(c)15] 

3.3 Equipment Federal Rule Standards 

3.3.1 The Permittee shall be subject to all applicable requirements of 40 CFR 60 - Standards of 

Performance for New Stationary Sources, Subpart A - General Provisions. 

[40 CFR 60 Subpart A] 

3.3.2 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam 

generating source, any gases which contain particulate matter in excess of 0.10 lb/MMBtu 

heat input. 

[40 CFR 60.42(a)(1), 391-3-1-.02(2)(d)2(iii)] 

3.3.3 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04) any gases that 

exhibit equal to or greater than 20 percent opacity (6-minute average), except for one 6- 

minute period per hour of not more than 27 percent opacity. 

[40 CFR 60.42(a)(2), 391-3-1-.02(2)(d)3] 

3.3.4 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam 

generating source, any gases which contain sulfur dioxide in excess of 1.2 lb/MMBtu heat 

input. 

[40 CFR 60.43(a)(2), 391-3-1-.02(2)(g)1(ii)] 

3.3.5 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam 

generating source, any gases which contain nitrogen oxides in excess of 0.7 lb/MMBtu heat 

input. 

[40 CFR 60.44(a)(3), 391-3-1-.02(2)(d)4(i)] 

3.3.6 The percent opacity from the coal handling system (Emission Unit ID CHS) shall not equal 

or exceed 20 percent. 

[40 CFR 60.254(a), 391-3-1-.02(2)(n)2]

 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 6 of 65 

3.3.7 The Permittee shall comply with the provisions of 40 CFR 60 Subpart OOO, "Standards of 

Performance of Nonmetallic Mineral Processing Plants" for the affected portion of the 

materials handling system (Emission Unit ID MHS). The affected portion shall include any 

grinding mill, screening operation, belt conveyor, and storage bin associated with the 

limestone handling process. In particular, the Permittee shall not discharge, or cause the 

discharge, into the atmosphere, 

[40 CFR 60 Subpart OOO] 

a. from any crusher, at which a capture system is not used, any fugitive emissions which 

exhibit greater than 12 percent opacity. 

b. from any stack, emissions which contain particulate matter in excess of 0.032 g/dscm 

(0.014 grains/dscf). 

c. from any screening operation, belt conveyor transfer point, bagging operation, storage 

bin, enclosed truck or railcar loading station, or from any other affected equipment 

any fugitive emissions which exhibit greater than 7 percent opacity. 

d. any visible emissions from; 

i. wet screening operations and subsequent screening operations, bucket elevators, 

and belt conveyors that process saturated material in the production line up to 

the next crusher, grinding mill or storage bin and, 

ii. screening operations, bucket elevators, and belt conveyors in the production line 

downstream of wet mining operations, where such screening operations, bucket 

elevators, and belt conveyors process saturated materials up to the first crusher, 

grinding mill, or storage bin in the production line. 

For processing equipment subject to Subpart OOO located inside a building, the Permittee 

shall comply with the above process limits (a, b, c, and d), or shall not discharge or cause 

the discharge into the atmosphere, any 

e. visible fugitive emissions from the building may not exhibit greater than 7 percent 

opacity. 

f. emissions from a powered building vent which contain particulate matter in excess of 

0.032 g/dscm (0.014 grains/dscf). 

Note: Unloading of nonmetallic minerals from movable vehicles designed to transport 

nonmetallic minerals from one location to another, including but not limited to: trucks, 

front end loaders, skip hoists, and railcars into any screening operation, feed hopper, or 

crusher is exempt from the requirements of this condition. 

[40 CFR 60 Subpart OOO, 40 CFR 60.672(d)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 7 of 65 

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

Standards for Hazardous Air Pollutants” as found in 40 CFR Subpart A, “General 

Provisions” and 40 CFR 63, Subpart UUUUU, "National Emission Standards for 

Hazardous Air Pollutants from Coal and Oil-Fired Electric Utility Steam Generating Units" 

for operation of steam generating units (Emission Unit IDs SG01, SG02, SG03, and SG04). 

[40 CFR 63, Subparts A and UUUUU] 

3.4 Equipment SIP Rule Standards 

3.4.1 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

startup boiler (Emission Unit IDs SB01 or SB02) any gases which contain particulate 

matter in excess of the rate derived from E = 0.5 x (10/R) 0.5 where E equals the allowable 

particulate emission rate in pounds per million Btu heat input and R equals the heat input in 

million Btu per hour. 

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

3.4.2 The Permittee shall not discharge or cause the discharge into the atmosphere from any 

startup boiler (Emission Unit IDs SB01 or SB02) any gases that exhibit equal to or greater 

than 20 percent opacity (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] 

3.4.3 The Permittee shall not fire any fuel in any start-up boiler (Emission Unit IDs SB01 or 

SB02) that contains greater than 3.0 percent sulfur, by weight. 

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

Coal and Ash Handling Requirements 

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

airborne from the following operations: 

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

a. Coal handling system (Emission Unit ID CHS) 

b. Ash handling system (Emission Unit ID AHS) 

c. Materials handling system (Emission Unit ID MHS) 

3.4.5 The percent opacity from the ash handling system (Emission Unit ID AHS), and materials 

handling system (Emission Unit ID MHS) shall not equal or exceed 20 percent. 

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

NOX Emission Limits Per Georgia Rule (jjj) 

3.4.6 Except as indicated in Condition 3.4.10 and 3.4.11, the Permittee shall not discharge, or 

cause the discharge, into the atmosphere from steam generating unit with Emission Unit ID 

SG01 at Plant Scherer (AFS No. 207-00008) NOX emissions in excess of 0.20 lb/MMBtu 

heat input on a 30-day rolling averaging period. This condition shall apply during the 

period May 1 through September 30 of each year. 

[391-3-1-.02(2)(jjj)5(i) and 6(i)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 8 of 65 

3.4.7 Except as indicated in Condition 3.4.10 and 3.4.11, the Permittee shall not discharge, or 

cause the discharge, into the atmosphere from steam generating unit with Emission Unit ID 

SG02 at Plant Scherer (AFS No. 207-00008) NOX emissions in excess of 0.17 lb/MMBtu 

heat input on a 30-day rolling averaging period. This condition shall apply during the 

period May 1 through September 30 of each year. 

[391-3-1-.02(2)(jjj)5(i) and 6(i)] 

3.4.8 Except as indicated in Condition 3.4.10 and 3.4.11, the Permittee shall not discharge, or 

cause the discharge, into the atmosphere from steam generating unit with Emission Unit ID 

SG03 at Plant Scherer (AFS No. 207-00008) NOX emissions in excess of 0.15 lb/MMBtu 

heat input on a 30-day rolling averaging period. This condition shall apply during the 

period May 1 through September 30 of each year. 

[391-3-1-.02(2)(jjj)5(i) and 6(i)] 

3.4.9 Except as indicated in Condition 3.4.10 and 3.4.11, the Permittee shall not discharge, or 

cause the discharge, into the atmosphere from steam generating unit with Emission Unit ID 

SG04 at Plant Scherer (AFS No. 207-00008) NOX emissions in excess of 0.16 lb/MMBtu 

heat input on a 30-day rolling averaging period. This condition shall apply during the 

period May 1 through September 30 of each year. 

[391-3-1-.02(2)(jjj)5(i) and 6(i)] 

3.4.10 If the Permittee does not comply with Condition Nos. 3.4.6, 3.4.7, 3.4.8, or 3.4.9, the 

Permittee shall demonstrate that NOX emissions, averaged over all affected units (Emission 

Unit IDs SG01, SG02, SG03 and SG04 at Plant Bowen (AFS No. 015-00011); SG01, 

SG02, SG03, SG04 at Plant Branch (AFS No. 237-0008); SG01, SG02, SG03, SG04 at 

Plant Hammond (AFS No. 115-00003); SGM1, SGM2 at Plant McDonough (AFS No. 067-

00003); SG01, SG02, SG03, SG04 at Plant Scherer (AFS No. 207-00008); SG01, SG02 at 

Plant Wansley (AFS No. 149-00001); and SG01, SG02, SG03, SG04, SG05, SG06, SG07 

at Plant Yates (AFS No. 077-00001)), do not exceed 0.18 lb/MMBtu heat input on a 30-day 

rolling averaging period. This condition shall apply during the period May 1 through 

September 30 of each year. 

[391-3-1-.02(2)(jjj)5(ii)] 

3.4.11 If the Permittee does not comply with Condition Nos. 3.4.6, 3.4.7, 3.4.8, or 3.4.9, the 

Permittee shall demonstrate that NOX emissions, averaged over all affected units (Emission 

Unit IDs SG01, SG02, SG03, SG04 at Plant Scherer (AFS No. 207-00008)), do not exceed 

0.17 lb/MMBtu heat input on a 30-day rolling average period. This condition shall apply 

during the period May 1 through September 30 of each year. 

[391-3-1-.02(2)(jjj)6(ii)] 

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

Material Handling System (Emission Unit ID MHS) any gases which contain particulate 

matter in excess of the rate derived from the equation noted below: 

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

a. For process input weight rate up to and including 30 tons per hour: 

E = 4.1P0.67; or 
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b. For process input weight rate above 30 tons per hour: 

 E = 55P0.11 – 40 

where E equals the allowable PM emission rate in pounds per hour and P equals the total 

dry process input weight rate in tons per hour. 

State Only Enforceable Condition. 

3.4.13 The Permittee shall not operate steam generating units (Emission Unit IDs SG01, SG02, 

SG03, or SG04) unless such source is equipped and operated with sorbent injection and a 

baghouse, except the Permittee is not required to operate the required control technology 

under the following conditions: 

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

a. Restarting an EGU when all Electric Utility Steam Generating Units [as listed in this 

Condition] at a facility are down and off-site power is not available (also known as a 

“Black Start”). 

b. Periods of startup of an EGU provided that such periods are consistent with the 

requirements outlined in the Georgia Rules for Air Quality Control 391-3-1-

.02(2)(a)7. 

c. Periods of shutdown of an EGU provided that such periods are consistent with the 

requirements outlined in the Georgia Rules for Air Quality Control 391-3-1-

.02(2)(a)7. 

d. Periods of scheduled and/or preventative maintenance of control technology 

equipment if such maintenance cannot reasonably be performed during a scheduled 

outage of the respective EGU. 

e. Periods of malfunction of EGU and/or control technology equipment provided that 

such periods are consistent with the requirements of Paragraph 391-3-1-.02(2)(a)7. 

f. Periods when the owner/operator is required to conduct the Relative Accuracy Test 

Audit and any other necessary periodic quality assurance procedures on the 

Continuous Emissions Monitoring System located on the bypass stack pursuant to 40 

CFR Part 75 or the Georgia Department of Natural Resources Procedures for Testing 

and Monitoring Sources of Air Pollutants. 

g. Periods when the owner/operator is required to conduct any performance tests on the 

bypass stack as required by state or federal air quality rules, air quality operating 

permits, or as ordered by the Division. 

h. Division approved periods of research and development of emission control 

technologies, provided that the unit does not exceed other applicable emission limits. 

For purposes of this subparagraph, the owner/operator shall submit a request for 

approval under this subparagraph at least 120 days prior to such date as well as 

including the following items: (1) length of time of research and development (R&D) 
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period; (2) identification of steps to take to minimize emissions in accordance with 

best operational practices during R&D period; (3) for periods of R&D lasting more 

than 48 hours during any 5-day period, a demonstration that any increase in emissions 

resulting from the R&D project that are above that which is allowed by this 

subparagraph (sss) will not cause or significantly contribute to a violation of any 

national ambient air quality standard or prevent compliance with any other applicable 

provisions. 

i. Any other occasion not covered by subparagraph a. through h., as approved by the 

Division. 

State Only Enforceable Condition. 

3.4.14 For steam generating unit SG03, effective December 31, 2012 for steam generating unit 

SG04, effective December 31, 2013 for steam generating unit SG02, and effective 

December 31, 2014 for steam generating unit SG01, the Permittee shall not operate each 

unit unless such source is equipped and operated with selective catalytic reduction, flue gas 

desulfurization, sorbent injection and a baghouse; provided that the owner or operator is not 

required to operate the selective catalytic reduction system during the non-ozone season 

months of January through April and October through December of each year, and except 

the Permittee is not required to operate the required control technology under the following 

conditions: 

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

a. Restarting an EGU when all Electric Utility Steam Generating Units [as listed in this 

Condition] at a facility are down and off-site power is not available (also known as a 

“Black Start”). 

b. Periods of startup of an EGU provided that such periods are consistent with the 

requirements outlined in the Georgia Rules for Air Quality Control 391-3-1-

.02(2)(a)7. 

c. Periods of shutdown of an EGU provided that such periods are consistent with the 

requirements outlined in the Georgia Rules for Air Quality Control 391-3-1-

.02(2)(a)7. 

d. Periods of scheduled and/or preventative maintenance of control technology 

equipment if such maintenance cannot reasonably be performed during a scheduled 

outage of the respective EGU. 

e. Periods of malfunction of EGU and/or control technology equipment provided that 

such periods are consistent with the requirements of Paragraph 391-3-1-.02(2)(a)7. 

f. Periods when the owner/operator is required to conduct the Relative Accuracy Test 

Audit and any other necessary periodic quality assurance procedures on the 

Continuous Emissions Monitoring System located on the bypass stack pursuant to 40 

CFR Part 75 or the Georgia Department of Natural Resources Procedures for Testing 

and Monitoring Sources of Air Pollutants.
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g. Periods when the owner/operator is required to conduct any performance tests on the 

bypass stack as required by state or federal air quality rules, air quality operating 

permits, or as ordered by the Division. 

h. Division approved periods of research and development of emission control 

technologies, provided that the unit does not exceed other applicable emission limits. 

For purposes of this subparagraph, the owner/operator shall submit a request for 

approval under this subparagraph at least 120 days prior to such date as well as 

including the following items: (1) length of time of research and development (R&D) 

period; (2) identification of steps to take to minimize emissions in accordance with 

best operational practices during R&D period; (3) for periods of R&D lasting more 

than 48 hours during any 5-day period, a demonstration that any increase in emissions 

resulting from the R&D project that are above that which is allowed by this 

subparagraph (sss) will not cause or significantly contribute to a violation of any 

national ambient air quality standard or prevent compliance with any other applicable 

provisions. 

i. Any other occasion not covered by subparagraph a. through h., as approved by the 

Division. 

3.4.15 For steam generating unit SG03, except for periods indicated in Condition No. 3.4.19, the 

Permittee shall not discharge, or cause the discharge, into the atmosphere, any gases which 

contain SO2 emissions in excess of 5 percent (0.05) of the potential combustion 

concentration (95 percent reduction) on a 30-day rolling average basis. 

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

3.4.16 Effective January 1, 2013 for steam generating unit SG04, except for periods indicated in 

Condition No. 3.4.19, the Permittee shall not discharge, or cause the discharge, into the 

atmosphere, any gases which contain SO2 emissions in excess of 5 percent (0.05) of the 

potential combustion concentration (95 percent reduction) on a 30-day rolling average 

basis. 

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

3.4.17 Effective January 1, 2014 for steam generating unit SG02, except for periods indicated in 

Condition No. 3.4.19, the Permittee shall not discharge, or cause the discharge, into the 

atmosphere, any gases which contain SO2 emissions in excess of 5 percent (0.05) of the 

potential combustion concentration (95 percent reduction) on a 30-day rolling average 

basis. 

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

3.4.18 Effective January 1, 2015 for steam generating unit SG01, except for periods indicated in 

Condition No. 3.4.19, the Permittee shall not discharge, or cause the discharge, into the 

atmosphere, any gases which contain SO2 emissions in excess of 5 percent (0.05) of the 

potential combustion concentration (95 percent reduction) on a 30-day rolling average 

basis. 

[391-3-1-.02(2)(uuu)2] 
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3.4.19 For purposes of this permit, requirements in Conditions 3.4.15, 3.4.16, 3.4.17, and 3.4.18 

do not apply during the following periods. 

 [391-3-1-.02(2)(uuu)4] 

a. Restarting an EGU when all Electric Utility Stream Generating Units [as listed in this 

Condition] at a facility are down and off-site power is not available (also known as a 

“Black Start”). 

b. Periods of startup of an Electric Utility Steam Generating Unit provided that such 

periods are consistent with the requirements outlined in the Georgia Rules for Air 

Quality Control 391-3-1-.02(2)(a)7. 

c. Periods of shutdown of an Electric Utility Steam Generating Unit provided that such 

periods are consistent with the requirements outlined in the Georgia Rules for Air 

Quality Control 391-3-1-.02(2)(a)7. 

d. Periods of scheduled and/or preventative maintenance of control technology 

equipment if such maintenance cannot reasonably be performed during a scheduled 

outage of the respective Electric Utility Steam Generating Unit. 

e. Periods of malfunction of an Electric Utility Steam Generating Unit and/or control 

technology equipment provided that such periods are consistent with the requirements 

outlined in the Georgia Rules for Air Quality Control 391-3-1-.02(2)(a)7. 

f. Periods when the Permittee is required to conduct the Relative Accuracy Test Audit 

(RATA) and any other necessary periodic quality assurance procedures on the 

Continuous Emissions Monitoring System (CEMS) located on the bypass stack 

pursuant to 40 CFR Part 75 or the Division’s Procedures for Testing and 

Monitoring Sources of Air Pollutants. 

g. Periods when the Permittee is required to conduct any performance testing on the 

bypass stack as required by State or Federal air quality rules, air quality operating 

permits or at the request of the Division. 

h. Division-approved periods of research and development of emission control 

technologies provided that the unit does not exceed other applicable emission limits. 

For purposes of this subparagraph, the owner/operator shall submit a request for 

approval under this subparagraph at least 120 days prior to such date as well as 

including the following items: (1) length of time of research and development (R&D) 

period; (2) identification of steps to take to minimize emissions in accordance with 

best operational practices during R&D period; (3) for periods of R&D lasting more 

than 48 hours during any 5-day period, a demonstration that any increase in emissions 

resulting from the R&D project that are above that which is allowed by this 

subparagraph (uuu) will not cause or significantly contribute to an violation of any 

national ambient air quality standard or prevent compliance with any other applicable 

provisions. 
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3.5 Equipment Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission 

Cap or Operating Limit 

None Applicable.
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PART 4.0 REQUIREMENTS FOR TESTING 

4.1 General Testing Requirements 

4.1.1 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. 

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

4.1.2 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. 

[391-3-1-.02(3)(a) and 40 CFR 63.7(b)(1)] 

4.1.3 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 Sections 3.2, 3.3, 3.4 and 3.5 which pertain to the 

emission units listed in Section 3.1 are as follows: 

a. Method 1 for the determination of sample point locations. 

b. Method 2 for the determination of stack gas flow rate. 

c. Method 3 or 3A for the determination of stack gas molecular weight. 

d. Method 3A or 3B for the determination of the emissions rate correction factor or 

excess air. 

e. Method 4 for the determination of stack gas moisture. 

f. Method 5 or Method 17, as applicable, for the determination of particulate matter 

concentration. 

g. Method 6 or 6C for the determination of sulfur dioxide concentration. 

h. Method 9 and the procedures contained in Section 1.3 of the above referenced 

document for the determination of opacity, 

i. Method 19, when applicable, to convert particulate matter, carbon monoxide, sulfur 

dioxide, and nitrogen oxide concentrations (i.e., grains/dscf for PM, ppm for gaseous 

pollutants), as determined using other methods specified in this section, to emission 

rates (i.e., lb/MMBtu), 
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j. The procedures contained in Section 2.116.2 of the above-referenced document shall 

be used for the determination of nitrogen oxides concentration from the steam 

generating units with emission units ID Nos. SG01, SG02, SG03, and SG04 for 

purposes of verifying compliance with Georgia Rule 391-3-1-.02(2)(jjj), 

k. Method 7E for the determination of nitrogen oxides concentration for the purposes 

other than verifying compliance with Georgia Rule 391-3-1-.02(2)(jjj), 

l. The procedures contained in Section 2.125.4 of the above-referenced document shall 

be used for the determination of sulfur dioxide emission rates from steam generating 

units with emission units ID Nos. SG01, SG02, SG03 and SG04 for purposes of 

verifying compliance with Georgia Rule 391-3-1-.02(2)(uuu). 

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

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

improvement or corrections that, in his opinion, render those methods or procedures, or 

portions thereof, more reliable. 

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

State Only Enforceable Condition

4.1.4 The Permittee shall provide, with the notification required under Condition 4.1.2, a test 

plan in accordance with Division guidelines. 

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

4.2 Specific Testing Requirements 

4.2.1 The Permittee shall conduct the following performance tests on the following emissions 

units at the frequency specified: 

a. Particulate matter tests on Steam Generating Units (Emission Unit ID Nos. SG01, 

SG02, SG03 and SG04) scrubber bypass stacks (ST01, ST02, ST03, and ST04). The 

tests shall be conducted for each unit within 30 days following 8760 operating hours 

of using the bypass stack or 60 months since the previous test of that unit, whichever 

comes first. Prior to the effective dates of Georgia Rule 391-3-1-.02(2)(uuu) for 

Units 1, 2, 3, and 4, the Permittee may, if results from the previous tests are fifty 

percent or less of the limitation in Condition 3.3.2, request that testing be deferred for 

a period of no greater than 8760 operating hours of the bypass stacks from the 

required test date. Such request shall be made in written form at least 30 days prior to 

the scheduled test. 

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

b. Particulate matter tests on Steam Generating Units (Emissions Unit ID Nos. SG01, 

SG02, SG03 and SG04) scrubber stacks (ST05, ST06, ST07 and ST08). The tests 

shall be conducted once every 60 calendar months or as requested by the Division. 

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

4.2.3 The Permittee shall conduct a repeat performance test(s) once every 5 years on the 

materials handling system (Emission Unit ID MHS) to ensure ongoing compliance with the 

emissions limitations contained in Condition 3.3.7 of this permit. Testing shall be 

conducted according to the methods and procedures contained in 40 CFR 60.675. 

[40 CFR 60.8, 40 CFR 60 Subpart OOO] 

4.2.4 The Permittee shall conduct the following performance test(s) on the following emissions 

units at the frequency specified: 

a. Initial and subsequent performance tests for sulfur dioxide emissions on Steam 

Generating Units 1, 2, 3, and 4 (Emission Unit IDs SG01, SG02, SG03 and SG04), as 

specified below. 

The initial performance test is based upon the 95 percent reduction required by Conditions 

3.4.15, 3.4.16, 3.4.17, and 3.4.18 for the first 30 successive boiler operating days following 

January 1, 2013 for steam generating unit SG04, January 1, 2014 for steam generating unit 

SG02, and January 1, 2015 for steam generating unit SG01. The initial performance tests 

are to be scheduled so that the first day of the 30 consecutive operating days is completed 

upon the first boiler operating day on or after the applicable effective dates. A separate 

performance test is completed at the end of each boiler operating day after the initial 

performance test, and a new 30-day percent reduction for Sulfur Dioxide (SO2) is 

calculated to show compliance with Conditions 3.4.15, 3.4.16, 3.4.17, and 3.4.18. 

Compliance with applicable percent reduction requirements is determined based on the 

average inlet and outlet SO2 emissions rates for the 30 successive boiler operating days. If 

the Permittee has not obtained the minimum quantity of emission data as required under 

Section 2.125.3(d) of the Division’s Procedures for Testing and Monitoring Sources of 

Air Pollutants, compliance of the affected facility with the emission requirements required 

by Conditions 3.4.15, 3.4.16, 3.4.17, and 3.4.18 for the day on which the 30-day period 

ends may be determined by the Director by following the applicable procedures in Section 

12.7 of Method 19 of Appendix A of the Procedures for Testing and Monitoring 

Sources of Air Pollutants. 

[391-3-1-.02(6)(b)1(i) and PTM Section 2.125] 
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PART 5.0 REQUIREMENTS FOR MONITORING (Related to Data Collection) 

5.1 General Monitoring Requirements 

5.1.1 Any continuous monitoring system required by the Division and installed by the Permittee 

shall be in continuous operation and data recorded during all periods of operation of the 

affected facility except for continuous monitoring system breakdowns and repairs. 

Monitoring system response, relating only to calibration checks and zero and span 

adjustments, shall be measured and recorded during such periods. 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] 

5.2 Specific Monitoring Requirements 

5.2.1 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. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. A Continuous Opacity Monitoring System (i.e. four COMS) one each located in each 

liner of the scrubber bypass stacks (ST01, ST02, ST03, and ST04). 

b. A Continuous Opacity Monitoring System (i.e. four COMS) located upstream (i.e. 

near the inlet) to each scrubber (FGD1, FGD2, FGD3 and FGD4). 

c. A Continuous Emissions Monitoring System (i.e. four CEMS), for the measurement 

of nitrogen oxides concentration (ppm) and diluent concentrations (either Oxygen or 

Carbon Dioxide, percent), located in each liner of the scrubber bypass stacks (ST01, 

ST02, ST03, and ST04). 

d. A Continuous Emissions Monitoring System (i.e. four CEMS), for the measurement 

of nitrogen oxides concentration (ppm) and diluent concentrations (either Oxygen or 

Carbon Dioxide, percent), to be located in each liner of the scrubber stacks (ST05, 

ST06, ST07, and ST08). 

e. The output of the CEMS described in Paragraphs 5.2.1.c and d above will also be 

displayed and recorded in terms of pounds per million British thermal units 

(lb/million Btu). 
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f. A Continuous Emissions Monitoring System (CEMS), for the measurement of sulfur 

dioxide concentration (ppm) and diluent concentrations (either Oxygen or Carbon 

Dioxide, percent), on Steam Generating Units 1, 2, 3 and 4 (Emission Unit IDs SG01, 

SG02, SG03 and SG04). Sulfur dioxide emissions are monitored in each liner of the 

bypass stack (ST01, ST02, ST03, and ST04), and in each liner of the scrubber stack 

(ST05, ST06, ST07, and ST08). For Unit 3, and effective January 1, 2013 for Unit 4, 

January 1, 2014 for Unit 2, and January 1, 2015 for Unit 1, sulfur dioxide emissions 

must be monitored at both the inlet, and outlet of the SO2 control device. The output 

of the CEMS shall be expressed in terms of pounds per million British thermal units 

(lb/MMBtu). 

g. On and after the sixtieth day after achieving the maximum production rate at a 

scrubber (FGD3 or FGD4), but not later than 180 days after initial startup, a 

Continuous Monitoring System (CMS) for the measurement of the number of FGD 

recycle pumps running (Control Device IDs FGD3 and FGD4) for Steam Generating 

Units 3 and 4 (Emission Unit ID Nos. SG03 and SG04). 

5.2.2 [Reserved] 

 State Only Enforceable Condition. 

5.2.3 The Permittee shall, upon written request by the Division, analyze any used oil to be burned 

in Steam Generating Units 1, 2, 3, and 4 (Emission Unit IDs SG01, SG02, SG03, and 

SG04). The sample(s) shall be obtained and analyzed using the following methods: 

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

a. The procedures described in U.S. Environmental Protection Agency document EPA600/2-80-018 (Samplers and Sampling Procedures for Hazardous Waste Streams) 

shall be used to obtain the sample. 

b. Method 6010B, contained in the SW-846 methods manual of U.S. Environmental 

Protection Agency’s Office of Solid Waste, shall be used to determine concentrations 

of arsenic, cadmium, chromium, and lead. 

c. SW-846 Method 9077C shall be used to determine total halogens. 

d. ASTM D93 shall be used to determine flash point. 

e. Polychlorinated Biphenyls (PCB) shall be determined using the test method described 

in U.S. Environmental Protection Agency Document EPA-600/4-81-045 (The 

Determination of Polychlorinated Biphenyls in Transformer Fluid and Waste Oil). 

5.2.4 The Permittee shall monitor sulfur dioxide emissions from Steam Generating Units SG01, 

SG02, SG03, and SG04 using the SO2 CEMS as required by Condition 5.2.1f. A 3-hour 

rolling average SO2 emission rate in pounds per million BTU shall be calculated. 

[40 CFR 60.45(b)(2) and 40 CFR 70.6(a)(3)(i)] 
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5.2.5 The following pollutant specific emission unit(s) (PSEU) is/are subject to the Compliance 

Assurance Monitoring (CAM) Rule in 40 CFR 64. 

 

Emission Unit Pollutant 

Steam Generating Unit 1 (SG01) Particulate Matter

Steam Generating Unit 2 (SG02) Particulate Matter

Steam Generating Unit 3 (SG03) Particulate Matter

Steam Generating Unit 4 (SG04) Particulate Matter

Permit conditions in this permit for the PSEU(s) listed above with regulatory citation 40 CFR 

70.6(a)(3)(i) are included for the purpose of complying with 40 CFR 64. In addition, the Permittee 

shall meet the requirements, as applicable, of 40 CFR 64.7, 64.8, and 64.9. 

[40 CFR 64] 

5.2.6 The Permittee shall comply with the performance criteria listed in the table below for the 

particulate matter emissions from steam generating unit SG01. 

 [40 CFR 64.6(c)(1)(iii)]

Performance Criteria 

[64.4(a)(3)] 

Indicator No. 1 

Opacity from SG01 exhaust 

A. Data Representativeness 

[64.3(b)(1)] 

The continuous opacity monitoring system 

(COMS) is located in the SG01 exhaust. 

The COMS was installed at a 

representative location in the stack per 40 

CFR 60, Appendix B, PS-1. 

B. Verification of Operational 

Status (new/modified 

monitoring equipment only) 

[64.3(b)(2)] 

Not applicable. 

C. QA/QC Practices and Criteria 

[64.3(b)(3)] 

The COMS was initially installed and 

evaluated per PS-1. Zero and span drift are 

checked daily and a quarterly filter audit is 

performed. 

D. Monitoring Frequency 

 [64.3(b)(4)] The opacity is monitored continuously. 

E. Data Collection Procedures 

[64.3(b)(4)] The data acquisition system (DAS) retains 

all 6-minute opacity data. 

F. Averaging Period 

[64.3(b)(4)] The 6-minute opacity data is used to 

calculate 3-hour block averages. 
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5.2.7 The Permittee shall comply with the performance criteria listed in the table below for the 

particulate matter emissions from steam generating unit SG02. 

 [40 CFR 64.6(c)(1)(iii)]

Performance Criteria 

[64.4(a)(3)] 

Indicator No. 1 

Opacity from SG02 exhaust 

G. Data Representativeness 

[64.3(b)(1)] 

The continuous opacity monitoring system 

(COMS) is located in the SG02 exhaust. 

The COMS was installed at a 

representative location in the stack per 40 

CFR 60, Appendix B, PS-1. 

H. Verification of Operational 

Status (new/modified 

monitoring equipment only) 

[64.3(b)(2)] 

Not applicable. 

I. QA/QC Practices and Criteria 

[64.3(b)(3)] 

The COMS was initially installed and 

evaluated per PS-1. Zero and span drift are 

checked daily and a quarterly filter audit is 

performed. 

J. Monitoring Frequency 

 [64.3(b)(4)] The opacity is monitored continuously. 

K. Data Collection Procedures 

[64.3(b)(4)] The data acquisition system (DAS) retains 

all 6-minute opacity data. 

L. Averaging Period 

[64.3(b)(4)] The 6-minute opacity data is used to 

calculate 3-hour block averages. 
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5.2.8 The Permittee shall comply with the performance criteria listed in the table below for the 

particulate matter emissions from steam generating unit SG03. 

 [40 CFR 64.6(c)(1)(iii)]

Performance Criteria 

[64.4(a)(3)] 

Indicator No. 1 

Opacity from FGD3 Inlet 

Indicator No. 2 

Number of recycle pumps running in 

FGD3 for SG03 

M. Data Representativeness 

[64.3(b)(1)] 

Opacity is an indicator of particulate 

matter collection and equipment 

performance of the ESP and baghouse. 

The number of FGD pumps running is 

an indicator of particulate matter 

collection and equipment performance 

of the FGD. 

N. Verification of Operational 

Status (new/modified 

monitoring equipment only) 

[64.3(b)(2)] 

Not applicable. Not applicable. 

O. QA/QC Practices and 

Criteria 

[64.3(b)(3)] 

The COMS was initially installed and 

evaluated per PS-1. Zero and span drift 

are checked daily and a quarterly filter 

audit is performed. The opacity 

monitors are calibrated as per 

manufacturer’s recommendations. 

The FGD controls are calibrated per 

manufacturer’s recommendations. 

P. Monitoring Frequency 

 [64.3(b)(4)] The opacity is monitored continuously. The number of FGD recycle pumps running is monitored continuously. 

Q. Data Collection Procedures 

[64.3(b)(4)] The data acquisition system (DAS) 

retains all 3-hour average opacity data. 

The DAS retains all 3-hour average 

FGD number of recycle pumps running 

data. 

R. Averaging Period 

[64.3(b)(4)] The 10-second opacity data is used to 

calculate 3-hour block averages. 

The 1-minute data is used to calculate 

3-hour block averages. 
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5.2.9 The Permittee shall comply with the performance criteria listed in the table below for the 

particulate matter emissions from steam generating unit SG04. 

 [40 CFR 64.6(c)(1)(iii)]

Performance Criteria 

[64.4(a)(3)] 

Indicator No. 1 

Opacity from FGD4 Inlet 

Indicator No. 2 

Number of recycle pumps running in 

FGD4 for SG04 

S. Data Representativeness 

[64.3(b)(1)] 

Opacity is an indicator of particulate 

matter collection and equipment 

performance of the ESP and baghouse. 

The number of FGD pumps running is 

an indicator of particulate matter 

collection and equipment performance 

of the FGD. 

T. Verification of Operational 

Status (new/modified 

monitoring equipment only) 

[64.3(b)(2)] 

Not applicable. Not applicable. 

U. QA/QC Practices and 

Criteria 

[64.3(b)(3)] 

The COMS was initially installed and 

evaluated per PS-1. Zero and span drift 

are checked daily and a quarterly filter 

audit is performed. The opacity 

monitors are calibrated as per 

manufacturer’s recommendations. 

The FGD controls are calibrated per 

manufacturer’s recommendations. 

V. Monitoring Frequency 

 [64.3(b)(4)] The opacity is monitored continuously. The number of FGD recycle pumps running is monitored continuously. 

W. Data Collection Procedures 

[64.3(b)(4)] The data acquisition system (DAS) 

retains all 3-hour average opacity data. 

The DAS retains all 3-hour average 

FGD number of recycle pumps running 

data. 

X. Averaging Period 

[64.3(b)(4)] The 10-second opacity data is used to 

calculate 3-hour block averages. 

The 1-minute data is used to calculate 

3-hour block averages. 

5.2.10 The Permittee shall, at all times, maintain the monitoring required by Conditions 5.2.6, 

5.2.7, 5.2.8, and 5.2.9, including but not limited to, maintaining necessary parts for routine 

repairs of the monitoring equipment. 

[40 CFR 64.7(b)] 

5.2.11 Except for, as applicable, monitoring malfunctions, associated repairs, and required quality 

assurance or control activities (including, as applicable, calibration checks and required 

zero and span adjustments), the Permittee shall conduct all monitoring in continuous 

operation (or shall collect data at all required intervals) at all times that the pollutantspecific emissions unit is operating. Data recorded during monitoring malfunctions, 

associated repairs, and required quality assurance or control activities shall not be used for 

purposes of CAM, including data averages and calculations, or fulfilling a minimum data 

availability requirement, if applicable. The Permittee shall use all the data collected during 

all other periods in assessing the operation of the control device and associated control sys 

tem. A monitoring malfunction is any sudden, infrequent, not reasonably preventable 

failure of the monitoring to provide valid data. Monitoring failures that are caused in part 

by poor maintenance or careless operation are not malfunctions. 

[40 CFR 64.7(c)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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5.2.12 Upon detecting an excursion or exceedance as defined in Condition 6.1.7b and c, the 

Permittee shall restore operation of the pollutant-specific emissions unit (including the 

control device and associated capture system) to its normal or usual manner of operation as 

expeditiously as practicable in accordance with good air pollution control practices for 

minimizing emissions. The response shall include minimizing the period of any startup, 

shutdown or malfunction and taking any necessary corrective actions to restore normal 

operation and prevent the likely recurrence of the cause of an excursion or exceedance 

(other than those caused by excused startup or shutdown conditions). Such actions may 

include initial inspection and evaluation, recording that operations returned to normal 

without operator action (such as through response by a computerized distribution control 

system), or any necessary follow-up actions to return operation to within the indicator 

range, designated condition, or below the applicable emission limitation or standard, as 

applicable. Determination of whether the Permittee has used acceptable procedures in 

response to an excursion or exceedance will be based on information available, which may 

include but is not limited to, monitoring results, review of operation and maintenance 

procedures and records, and inspection of the control device, associated capture system, and 

the process. 

[40 CFR 64.7(d)(1) and (2)] 

5.2.13 If the Permittee identifies a failure to achieve compliance with an emission limitation or 

standard for which the approved monitoring in Conditions 5.2.6, 5.2.7, 5.2.8, and 5.2.9 did 

not provide an indication of an excursion or exceedance while providing valid data, or the 

results of compliance or performance testing document a need to modify the existing 

indicator ranges or designated conditions, the Permittee shall promptly notify the permitting 

authority and, if necessary, submit a proposed modification to the part 70 or 71 permit to 

address the necessary monitoring changes. Such a modification may include, but is not 

limited to, reestablishing indicator ranges or designated conditions, modifying the 

frequency of conducting monitoring and collecting data, or the monitoring of additional 

parameters. 

[40 CFR 64.7(e)] 

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

measurement of the indicated parameters on the following equipment. Where such 

performance specification(s) exist, each system shall meet the applicable performance 

specification(s) of the Division's monitoring requirements. Data shall be recorded at the 

frequency specified below. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. Pressure drop for baghouses (APCD IDs BH01, BH02, BH03, and BH04) installed on 

steam generating units (Emission Unit IDs SG01, SG02, SG03, and SG04). The 

pressure drop shall be monitored and data recorded as specified in Conditions 5.2.15. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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5.2.15 The Permittee shall develop and implement a Preventive Maintenance Program for the 

baghouses specified in condition 5.2.14 to assure that the provisions of condition 8.17.1 are 

met. The program shall be subject to review and, if necessary to assure compliance, 

modification by the Division and shall include the pressure drop ranges that indicate proper 

operation for each bag house. At a minimum, the following operation and maintenance 

checks shall be made on at least a weekly basis, and a record of the findings and corrective 

actions taken shall be kept in a maintenance log: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Record the pressure drop across each baghouse and ensure that it is within the 

appropriate range. 

b. For baghouses equipped with compressed air cleaning systems, check the system for 

proper operation. This may include checking for low pressure, leaks, proper 

lubrication, and proper operation of timer and valves. 

c. For baghouses equipped with reverse air cleaning systems, check the system for 

proper operation. This may include checking damper, bypass, and isolation valves 

for proper operation. 

d. For baghouses equipped with shaker cleaning systems, check the system for proper 

operation. This may include checking shaker mechanism for loose or worn bearings, 

drive components, mounting; proper operation of outlet/isolation valves; proper 

lubrication. 

e. Check dust collector hoppers and conveying systems for proper operation. 

5.2.16 The Permittee shall install continuous temperature monitors on the inlet of baghouses 

(APCD IDs BH01, BH02, BH03, and BH04) that receive gases from steam generating units 

(Emission Unit IDs SG01, SG02, SG03, and SG04) and record the time and date of each 

incident when the temperature exceeds the filter bag design temperature. The Permittee 

shall record the filter bag design temperature for each baghouse listed. Such records and 

any supporting calculations shall be made available for inspection. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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5.2.17 Once each day or portion of each day of operation, the Permittee shall inspect all affected 

emission units as identified in Condition 3.3.7 in the Material Handling System by 

conducting a walk-through of the facility and noting the occurrence of the following (a 

check list or other similar log may be used for this purpose.) 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. Any emissions unit which exhibits any visible emissions. 

b. Any emissions unit that exhibits obvious mechanical failure or malfunction and 

results in increased air emissions. 

For each unit noted with visible emissions, mechanical problems, or malfunctions, the 

Permittee shall take corrective action with twelve (12) hours and re-inspect the unit when it 

is operated next to verify that no visible emissions exist and that any mechanical problems 

or malfunctions have been corrected. The Permittee shall maintain a log of all corrective 

actions taken, including the dates and times of corrective actions taken and re-inspections. 

5.2.18 Within 180 days of startup of the scrubbers FGD1 and FGD2 the Permittee shall conduct 

testing to determine compliance indicators(s) and submit an updated Compliance Assurance 

Monitoring (CAM) Plan for the control of particulate emissions from Steam Generating 

Units 1 and 2 (Emission Unit IDs SG01 and SG02) to the scrubber stack liners (ST05 and 

ST06). 

[40 CFR 64.4(e)] 

State-Only Enforceable Condition. 

5.2.19 The Permittee shall install, calibrate, maintain, and operate monitoring devices to 

continuously monitor and record the measurement of the indicated parameters on the 

following equipment. Where such performance specifications exist, each system shall meet 

the applicable performance specifications of the Division’s monitoring requirements. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. The electrical output of each steam generating unit, SG01, SG02, SG03, and SG04 in 

megawatts (MW). 

b. The Activated Carbon Injection (ACI) rate in pounds per hour of each steam 

generating unit, SG01, SG02, SG03 and SG04. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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State-Only Enforceable Condition. 

5.2.20 Using the data required in Conditions 5.2.19a and 5.2.19b, the Permittee shall calculate the 

minimum Activated Carbon Injection (ACIm) rates required for SG01, SG02, SG03, and 

SG04 using the following equation: 

ACIm rate (lb/hr) = 0.0952 * MW + 16.2 

The value of ACIm shall be compared to the actual ACI rates for each applicable steam 

generating unit for each operating minute as required in Condition 5.2.19b. For each hour 

or portion of each hour of operation, a positive signal will be recorded if the ACI rates for 

each steam generating unit (Emission Unit IDs SG01, SG02, SG03, and SG04) are greater 

than or equal to the calculated minimum ACIm for at least 30 minutes each hour. 

5.2.21 The CEMS required by Condition 5.2.1f shall be operated and data recorded during all 

periods of operation of the affected steam generating units with emission unit IDs SG01, 

SG02, SG03 and SG04 including periods of startup, shutdown, malfunction or emergency 

conditions, except for CEMS breakdowns, repairs, calibration checks, and zero and span 

adjustments and any period allowed under Condition 3.4.19. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

5.2.22 The Permittee shall obtain SO2 emission data for at least 75 percent of all operating hours 

for each 30 successive boiler operating days. The 1-hour averages required under Section 

1.4(h) of the Division's Procedures for Testing and Monitoring Sources of Air 

Pollutants are expressed in ng/J (lb/MMBTU) heat input and used to calculate the average 

emission rates under Georgia Rule 391-3-1-.02(2)(uuu). The 1-hour averages are calculated 

using the data points required under Section 1.4(h)(2) of the referenced document. If the 

minimum data requirement of this condition is not met, the Permittee may use the 

procedures of Section 2.125.3(f) of the Division's Procedures for Testing and Monitoring 

Sources of Air Pollutants to supplement the data collected. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

5.2.23 The Permittee is required to prepare and submit to the Division for approval a unit specific 

monitoring plan as required by Section 2.125.3(i) of the Division’s Procedures for Testing 

and Monitoring Sources of Air Pollutants for the SO2 CEMS required by Condition 

5.2.1f, at least 45 days before commencing certification testing of the monitoring system. 

The Permittee shall comply with the requirements in the plan. The plan must address the 

following information: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. Installation of the CEMS sampling probe or other interface at a measurement location 

relative to each affected process unit such that the measurement is representative of 

the exhaust emissions (e.g., on or downstream of the last control device). 

b. Performance and equipment specifications for the sample interface, the pollutant 

concentration or parametric signal analyzer, and the data collection and reduction 

systems; 
Title V Permit 

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c. Performance evaluation procedures and acceptance criteria. (e.g., calibrations, relative 

accuracy test audits (RATA), etc.) 

d. Operation and maintenance procedures in accordance with the general requirements 

of 40 CFR Part 75 or other acceptable procedures approved by the Division. 

e. Ongoing recordkeeping and reporting procedures. 

5.2.24 The SO2, CO2, and O2 CEMS required by Condition 5.2.1 shall be installed, certified, and 

operated in accordance with the applicable procedures in Performance Specification 2 or 3 

in Appendix B of the Division’s Procedures for Testing and Monitoring Sources of Air 

Pollutants or in accordance with the procedures in Appendices A and B to 40 CFR Part 75. 

Daily calibration drift assessments and quarterly accuracy determinations shall be done in 

accordance with Procedure 1 in Appendix F of the Division’s Procedures for Testing and 

Monitoring Sources of Air Pollutants. A data assessment report (DAR) shall be prepared 

according to Section 7 of Procedure 1 in Appendix F and shall be maintained on site and 

available for inspection or submittal to the Director. The Permittee may elect to implement 

alternative data accuracy procedures in Section 2.125.3(j) of the Division’s Procedures for 

Testing and Monitoring Sources of Air Pollutants. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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PART 6.0 RECORD KEEPING AND REPORTING REQUIREMENTS 

6.1 General Record Keeping and Reporting Requirements 

6.1.1 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(i) and 40 CFR 70.6(a)(3)] 

6.1.2 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 emissions 

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

The Permittee shall submit a written report that 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), 391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(3)(iii)(B)] 

6.1.3 The Permittee shall submit written reports of any failure to meet an applicable emission 

limitation or standard contained in this permit and/or any failure to comply with or 

complete a work practice standard or requirement contained in this permit which are not 

otherwise reported in accordance with Conditions 6.1.4 or 6.1.2. Such failures shall be 

determined through observation, data from any monitoring protocol, or by any other 

monitoring which is required by this permit. The reports shall cover each semiannual 

period ending June 30 and December 31 of each year, shall be postmarked by August 29, 

and February 28, respectively following each reporting period, and shall contain the 

probable cause of the failure(s), duration of the failure(s), and any corrective actions or 

preventive measures taken. 

[391-3-1-.03(10)(d)1.(i) and 40 CFR 70.6(a)(3)(iii)(B)] 

6.1.4 The Permittee shall submit a written report containing any 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 May 30, August 29, November 29, and February 28, 

respectively following each reporting period. 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 and 40 CFR 70.6(a)(3)(iii)(A)] 

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 process operating time during each reporting period. 
Title V Permit 

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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. Include 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 by a Responsible Official that, based on information and belief formed 

after reasonable inquiry, the statements and information in the report are true, 

accurate, and complete. 

6.1.5 Where applicable, the Permittee shall keep the following records: 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(3)(ii)(A)] 

a. The date, place, and time of sampling or measurement; 

b. The date(s) analyses were performed; 

c. The company or entity that performed the analyses; 

d. The analytical techniques or methods used; 

e. The results of such analyses; and 

f. The operating conditions as existing at the time of sampling or measurement. 

6.1.6 The Permittee shall maintain files of all required measurements, including continuous 

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

continuous monitoring system or monitoring device calibration checks; and 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(10)(d)1(i) and 40 CFR 70.6 (a)(3)(ii)(B)] 
Title V Permit 

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Page 30 of 65 

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

required in Condition 6.1.4, the following excess emissions, exceedances, and excursions 

shall be reported: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. Excess emissions: (means for the purpose of this Condition and Condition 6.1.4, any 

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

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

i. Excess emissions of nitrogen oxides as described in Condition 6.2.10a. 

ii. Excess emissions of nitrogen oxides as described in Condition 6.2.10b. 

iii. Any six-minute average opacity, as recorded by the COMS for any steam 

generating unit (Emission Unit IDs SG01, SG02, SG03, and SG04) that exceeds 

20 percent opacity (6-minute average), except for one 6-minute period per hour 

of not more than 27 percent opacity. 

iv. Any 3-hour average nitrogen oxide emissions rate, as measured by the CEMS 

installed on steam generating units (Emission Unit IDs SG01, SG02, SG03, and 

SG04) that exceeds 0.7 lb/MMBtu heat input. 

v. Any 3-hour average sulfur dioxide emission rate, as measured by the CEMS 

installed on steam generating units (Emission Unit IDs SG01, SG02, SG03, and 

SG04), that exceeds 1.2 lb/MMBtu heat input. 

b. Exceedances: (means for the purpose of this Condition and Condition 6.1.4, 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 time fuel fired in any start-up boiler (Emission Unit IDs SB01 or SB02) 

has a sulfur content which exceeds 3.0 percent sulfur, by weight. 

ii. An ozone season (May 01 through September 30) total NOX emission rate 

which exceeds 32,335.8 tons from the applicable equipment specified in 

Condition 3.2.6. 

iii. Any 30 day rolling average SO2 percent reduction that is calculated in 

accordance with the procedures of Condition 6.2.14 that is less than 95% for 

SG01, SG02, SG03, and SG04. This condition is effective for SG03 and should 

become effective January 1, 2013 for SG04, January 1, 2014 for SG02, and 

January 1, 2015 for SG01. 
Title V Permit 

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c. Excursions: (means for the purpose of this Condition and Condition 6.1.4, 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. For Source 1 (Emission Unit ID SG01), any three-hour block average during 

which the arithmetic average opacity, as measured by the COMS, exceeds 20 

percent. A three-hour block average shall be defined as any one of the eight 

consecutive three-hour time periods between 12:00 midnight and the following 

midnight. 

ii. For Source 2 (Emission Unit ID SG02), any three-hour block average during 

which the arithmetic average opacity, as measured by the COMS, exceeds 20 

percent. A three-hour block average shall be defined as any one of the eight 

consecutive three-hour time periods between 12:00 midnight and the following 

midnight. 

iii. For Source 3 (Emission Unit ID SG03), any three-hour block average during 

which the arithmetic average opacity, as measured by the COMS, exceeds 20 

percent and less than four FGD recycle pumps are running. A three-hour block 

average shall be defined as any one of the eight consecutive three-hour time 

periods between 12:00 midnight and the following midnight. 

iv. For Source 4 (Emission Unit ID SG04), any three-hour block average during 

which the arithmetic average opacity, as measured by the COMS, exceeds 20 

percent and less than four FGD recycle pumps are running. A three-hour block 

average shall be defined as any one of the eight consecutive three-hour time 

periods between 12:00 midnight and the following midnight. 

v. Any time coal derived synthetic fuel fired in any steam generating unit 

(Emission Unit IDs SG01, SG02, SG03, or SG04) does not meet the 

specification of Condition 3.2.1e. 

vi. Each occurrence when the temperature at the inlet of any baghouse specified in 

Condition 5.2.16 exceeds the filter bag design temperature recorded in 

accordance with Condition 5.2.16. 

vii. Any instance a weekly preventative maintenance check required by Condition 

5.2.15 reveals a problem that is not resolved according to the Preventive 

Maintenance Program. 

viii. For sources specified in Condition 5.2.17, any required daily inspection during 

which any emissions unit which exhibits any visible emissions that is not 

corrected within 12 hours of the observation. 
Title V Permit 

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State-Only Enforceable Condition. 

ix. Any 30 consecutive operating day period in which actual ACI rate recorded by 

condition 5.2.19b is less than the minimum ACI rate determined in condition 

5.2.20 for 10% or more of the operating hours during that period, excluding 

periods described in Georgia Rules for Air Quality Control 391-3-1-

.02(2)(sss)17. 

6.2 Specific Record Keeping and Reporting Requirements 

State Only Enforceable Condition.

6.2.1 The Permittee shall retain monthly records of all fuel burned (except c, d and f below which 

shall be monitored on an as received basis), in the steam generating units with Emission 

Unit IDs SG01, SG02, SG03, and SG04, for five years after the date and year of record. 

The records shall be available for inspection or submittal to the Division, upon request, and 

contain the following: 

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

a. Quantity (tons) of coal burned. 

b. Aggregate total quantity (gallons) of distillate oil, No. 2 fuel oil, biodiesel, biodiesel 

blends, or very low sulfur oil burned. 

c. Quantity (tons) of sawdust received. 

d. Quantity (tons) of biomass received. 

e. Quantity (gallons) of used oil burned. 

f. Quantity (tons) of coal-derived synthetic fuel received. 

State Only Enforceable Condition.

6.2.2 The Permittee shall maintain records of representative samples of the coal and sawdust 

burned in the steam generating units (Emission Unit IDs SG01, SG02, SG03, and SG04) 

for five years after the date and year of record. The records shall be available for inspection 

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

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

a. Percent ash content of coal. 

b. Heat content (Btu per pound) of sawdust. 
Title V Permit 

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6.2.3 For each shipment of fuel oil received, the Permittee shall obtain from the supplier of the 

fuel oil, a statement certifying that the oil complies with the specifications of fuel oil 

contained in ASTM D396, ASTM D975, or ASTM D6751. As an alternative to the 

procedure described above, the Permittee may, for each shipment of 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, D1552, or by some other test method approved by the US EPA and 

acceptable to the Division. 

[391-3-1-.02(6)(b)1(i) and 40 CFR 70.6(a)(3)(i)] 

6.2.4 The Permittee shall obtain from the supplier a statement certifying that each shipment of 

coal derived synthetic fuel to be received complies with the specifications as described in 

Condition 3.2.1e. 

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

6.2.5 For each trainload of coal that is unloaded at the facility, the Permittee shall observe the 

unloading process to ensure that the dust suppression system for the coal handling system 

(Emission Unit ID CHS) is working properly and that all spray nozzles are operating with 

adequate water pressure and flow for effective dust control. The Permittee shall record the 

date and time that any corrective measures were taken to ensure that the dust suppression 

system is working properly and shall describe the measures taken. 

[40 CFR 60.254(c) and 40 CFR 70.6(a)(3)(i)] 

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

3.4.4b to suppress fugitive dust from the ash handling system (Emission Unit ID AHS). 

Such records shall include the date and time of occurrence and a description of the actions 

taken. 

[391-3-1-.02(6)(b)(1)(i) and 40 CFR 70.6(a)(3)(i)] 

Record Keeping Requirements for the Ozone Season NOX Emission Caps 

6.2.7 The Permittee shall use the data obtained from the NOX CEMS to compute the monthly 

mass emission rate, in tons per calendar month, of NOX from the following coal-fired steam 

generating units on a combined basis: Emission Unit IDs SG01, SG02, SG03, and SG04 at 

Plant Bowen (AFS No. 015-00011); Emission Unit IDs SG01, SG02, SG03, and SG04 at 

Plant Branch (AFS No. 237-00008); Emission Unit IDS SG01, SG02, SG03, and SG04 at 

Plant Hammond (AFS No. 115-00003); Emission Unit IDS SGM1 and SGM2 at Plant 

McDonough (AFS No. 067-00003); Emission Unit IDs SG01, SG02, SG03, SG04 at Plant 

Scherer (AFS No. 207-00008); Emission Unit IDS SG01 and SG02 at Plant Wansley (AFS 

No. 149-00001); Emission Unit IDs SG01, SG02, SG03, SG04, SG05, SG06, and SG07 at 

Plant Yates (AFS No. 077-00001). This emission rate must include emissions from startup, 

shutdown, and malfunction. This condition only applies during the ozone season (May 01 

to September 30). 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 
Title V Permit 

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Page 34 of 65 

6.2.8 The Permittee shall use the records required by Condition 6.2.7 to determine the ozone 

season total emission rate, in tons, of NOX from the following coal-fired steam generating 

units on a combined basis: Emission Unit IDs SG01, SG02, SG03, and SG04 at Plant 

Bowen (AFS No. 015-00011); Emission Unit IDs SG01, SG02, SG03, and SG04 at Plant 

Branch (AFS No. 237-00008); Emission Unit IDs SG01, SG02, SG03, and SG04 at Plant 

Hammond (AFS No. 115-00003); Emission Unit IDs SGM1 and SGM2 at Plant 

McDonough (AFS No. 067-00003); Emission Unit IDs SG01, SG02, SG03, SG04 at Plant 

Scherer (AFS No. 207-00008); Emission Unit IDs SG01 and SG02 at Plant Wansley (AFS 

No. 149-00001); Emission Unit IDs SG01, SG02, SG03, SG04, SG05, SG06, and SG07 at 

Plant Yates (AFS No. 077-00001). This emission rate must include emissions from startup, 

shutdown, and malfunction. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

Record Keeping for the Verification of Georgia Rule (jjj) NOX Emission Limits 

6.2.9 The Permittee shall determine compliance with the NOX emissions limitations in Condition 

Nos. 3.4.6 through 3.4.10 using emissions data acquired by the NOX CEMS. The 30-day 

rolling average shall be determined as follows: 

[391-3-1-.02(6)(b)1(i) and 40 CFR 70.6(a)(3)(i)]

a. The first 30-day averaging period shall begin on the first operating day of the ozone 

season. 

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

any 30 successive operating days during the period of the ozone season. 

c. The last 30-day averaging period shall end on the last operating day of the ozone 

season. 

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

each operating day. 

e. 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. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 35 of 65 

6.2.10 The Permittee shall determine compliance with the limitation using the procedures of 

Section 2.116.2 of the Division’s Procedures for Testing and Monitoring Sources of Air 

Pollutants. The Permittee shall maintain the records specified in Section 2.116.4 of the 

aforementioned procedures document and use these records to prepare a quarterly report. 

Reportable emissions are any calculated 30-day rolling average NOX emissions rate which 

exceeds the limit established in Condition Nos. 3.4.6, 3.4.7, 3.4.8, or 3.4.9, whichever is 

applicable. Excess emissions are those that: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Exceed an area-wide average limit in Condition Nos. 3.4.10 as well as the source’s 

respective Alternative Emission Limitation as specified in Condition Nos. 3.4.6, 

3.4.7, 3.4.8, or 3.4.9, whichever is applicable. 

b. Exceed the plant-wide average limit in Condition No. 3.4.11 as well as the source’s 

respective Alternative Emission Limitation as specified in Condition Nos. 3.4.6, 

3.4.7, 3.4.8, or 3.4.9, whichever is applicable 

Reporting Requirements 

6.2.11 The Permittee may submit, via electronic media, any report required by Part 6.0 of this 

permit provided such format has been approved by the Division. 

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

6.2.12 The Permittee shall submit written reports to the Division of reportable emissions under 

Condition 6.2.10 (excess emissions would be reported per Condition 6.1.7) for each 

calendar quarter ending June 30 (April excluded) and September 30. All reports shall be 

postmarked by August 29 and November 29, respectively, following each reporting period. 

In the event that there have not been any reportable emissions during a reporting period, the 

report should state as such. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

6.2.13 In accordance with the provisions of 40 CFR 60.7, for any equipment which is subject to 

the New Source Performance Standard, 40 CFR 60 Subpart OOO, the Permittee shall 

furnish the Division written notification of the actual date of initial startup of NSPS 

equipment including equipment description, manufacturer, and serial number if available 

postmarked within 15 days after such date. 

[40 CFR 60 Subpart OOO] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 36 of 65 

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

No. 3.4.15, 3.4.16, 3.4.17, and 3.4.18 based on the average emission rate for 30 successive

boiler operating days. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. The percent of potential SO2 emissions (%Ps) to the atmosphere shall be computed 

using the following equation: 

%Ps = 

100

(100 % )(100 % ) − Rf − Rg

Where: 

%Ps = Percent of potential SO2 emissions, percent; 

%Rf = Percent reduction from fuel pretreatment, percent; and 

%Rg = Percent reduction by SO2 control system, percent. 

b. The procedures of Method 19 may be used to determine percent reduction (%Rf) of 

sulfur by such processes as fuel pretreatment (physical coal cleaning, 

hydrodesulfurization of fuel oil, etc.), coal pulverizers, and bottom and fly ash 

interactions. This determination is optional. 

c. The procedures in Method 19 shall be used to determine the percent SO2 reduction 

(%Rg) of any SO2 control system. Alternatively, a combination of an “as fired” fuel 

monitor and emission rates measured after the control system, following the 

procedures in Method 19, may be used if the percent reduction is calculated using the 

average emission rate from the SO2 control device and the average SO2 input rate 

from the “as fired” fuel analysis for 30 successive boiler operating days.
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 37 of 65 

6.2.15 The Permittee shall determine compliance with the limitation in Conditions 3.4.15, 3.4.16, 

3.4.17, and 3.4.18, using the procedures of Section 2.125.4 of the Division’s Procedures for 

Testing and Monitoring Sources of Air Pollutants. The Permittee shall maintain the records 

specified in Section 2.125.5 of the aforementioned document and the records used to 

prepare a quarterly report. Reportable emissions are any calculated 30-day rolling average 

SO2 emissions reduction which exceeds the limit established in Conditions 3.4.15, 3.4.16, 

3.4.17, and 3.4.18. The following information shall be maintained for each 24-hour 

reporting period: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. Calendar date. 

b. Percent reduction of the potential combustion concentration of SO2 for each 30 

successive boiler operating days; reasons for non-compliance with the emissions 

standards; and description of corrective actions taken. 

c. Identification of the boiler operating days for which pollutant or diluent data have not 

been obtained by an approved method for at least 75 percent of the hours of operation 

of the facility; justification for not obtaining sufficient data; and description of 

corrective actions taken. 

d. Identification of the times when emissions data have been excluded from the 

calculation of average emission rates because of startup, shutdown, or other reasons, 

and justification for excluding data for reasons other than startup or shutdown 

conditions. 

e. Identification of “F” factor used for calculations, method of determination, and type 

of fuel combusted. 

f. Identification of times when hourly averages have been obtained based on manual 

sampling methods. 

g. Identification of the times when the pollutant concentration exceeded full span of the 

CEMS. 

h. Description of any modifications to CEMS which could affect the ability of the 

CEMS to comply with Performance Specifications 2 or 3. 

i. Results of any daily calibration error tests or quarterly accuracy assessment as 

required under Section 2.125.3(j) of the aforementioned document that does not meet 

the applicable accuracy specification and the subsequent acceptable daily calibration 

error test or quarterly accuracy assessment. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 38 of 65 

6.2.16 The Permittee shall submit written reports to the Division of reportable emissions under 

Condition 6.2.15 (excess emissions would be reported per Condition 6.1.7) for each 

calendar quarter. All reports shall be postmarked by May 30, August 29, November 29, 

and February 28, respectively, following each reporting period. In the event that there have 

not been any reportable emissions during a reporting period, the report should state as such. 

The Permittee shall determine compliance with the limitation using the procedures of 

Section 2.125.4 of the Division’s Procedures for Testing and Monitoring Sources of Air 

Pollutants. The Permittee shall maintain the records specified in Section 2.125.5 of the 

aforementioned procedures document and use these records to prepare a quarterly report. 

Reportable emissions are any calculated 30-day rolling average SO2 emissions rate which 

exceeds the limit established in Conditions 3.4.15, 3.4.16, 3.4.17, and 3.4.18, whichever is 

applicable. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

6.2.17 In the event the minimum quantity of emissions data as required by Section 2.125.4 of the 

Division’s Procedures for Testing and Monitoring Sources of Air Pollutants is not 

obtained for any 30 successive boiler operating days, the following information obtained 

under the requirements of Section 2.125.2(d) of the aforementioned document is reported to 

the Division for that 30-day period. 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)] 

a. The number of hourly averages available for outlet emission rates (no) and inlet 

emission rates (ni), as applicable. 

b. The standard deviation of hourly averages for outlet emission rates (so) and inlet 

emission rates (si), as applicable. 

c. The lower confidence limit for the mean outlet emission rate (Eo*) and the upper 

confidence limit for the mean inlet emission rate (Ei*), as applicable. 

d. The applicable potential combustion concentration. 

e. The ratio of the upper confidence limit for the mean outlet emission rate (Eo*) and the 

allowable emission rate (Estd), as applicable. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 39 of 65 

6.2.18 For any periods for which SO2 emissions data are not available, the Permittee shall submit a 

signed statement to the Division indicating if any changes were made in operation of the 

emission control system during the period of data unavailability. Operations of the control 

system and affected facility during periods of data unavailability are to be compared with 

operation of the control system and affected facility before and following the period of data 

unavailability. Within the signed statement, the Permittee must include: 

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Verification of whether the required CEMS calibration, span, and drift checks or 

other periodic audits have or have not been performed as specified. 

b. The data used to show compliance was or was not obtained in accordance with 

approved methods and procedures of this text and is representative of plant 

performance. 

c. The minimum data requirements have or have not been met; or, the minimum data 

requirements have not been met for errors that were unavoidable. 

d. Compliance with the standards has or has not been achieved during the reporting 

period. 

6.2.19 The Permittee shall submit results of each RATA required under Section 2.125.3(j) of the 

Division’s Procedures of Monitoring and Testing of Air Pollutants within 60 days of the 

completion of RATA. 

[391-3-1-.03(6)(b)1 and 40 CFR70.6(a)(3)(i) 

6.2.20 The Permittee shall document and maintain a record of the following information related to 

the high pressure steam turbine upgrades for steam generating units SG01, SG02, SG03, 

and SG04. 

 [391-3-1-.02(7)(b)15.(i)(I)] 

a. A description of the project; 

b. Identification of the emissions unit(s) whose emissions of a regulated NSR pollutant 

could be affected by the project; and 

c. A description of the applicability test used to determine that the project is not a major 

modification for any regulated NSR pollutant, including the baseline actual emissions, 

the projected actual emissions, the amount of emissions excluded under Georgia Rule 

391-3-1-.02(7)(a)2.(ii)(II)III of this rule and an explanation for why such amount was 

excluded, and any netting calculations, if applicable. 

The records shall be retained for a period of 15 years following resumption of regular 

operations after the changes. 

 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 40 of 65 

6.2.21 The Permittee shall monitor CO and VOC from each steam generating unit (Emission Units 

SG01, SG02, SG03, and SG04) and calculate and maintain a record of the annual 

emissions, in tons-per-year on a calendar basis, for a period of ten years following 

resumption of regular operations after installation of the upgraded high pressure steam 

turbines, and control equipment for each unit. These records shall be retained for a period 

of five years past the end of each calendar year. 

If the Permittee is required to or elects to exclude emissions associated with startups, 

shutdowns, and/or malfunctions from estimations of projected actual emissions for PSD 

applicability purposes as allowed by Georgia Rule 391-3-1-.02(7)(a)2.(ii)(II)II, the 

Permittee may exclude such emissions from the calculation of annual emissions. 

 [391-3-1-.02(7)(b)15.(i)(III)] 

The Permittee shall calculate the actual increase in emissions due to demand growth, in 

tons per year on a calendar year basis, for a period 10 years following resumption of regular 

operations after the changes. These records shall be retained for a period of five years past 

the end of each calendar year. 

6.2.22 The Permittee shall submit a report to the Division within 60 days after the end of each 

year during which records must be generated under Condition 6.2.21 setting out the unit’s 

annual emissions of CO and VOC, from each steam generating unit (Emission Units SG01, 

SG02, SG03, SG04) during the calendar year that preceded submission of the report. 

[391-3-1-.02(7)(b)15.(i)(V)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 41 of 65 

PART 7.0 OTHER SPECIFIC REQUIREMENTS 

7.1 Operational Flexibility 

7.1.1 The Permittee may make Section 502(b)(10) changes as defined in 40 CFR 70.2 without 

requiring a Permit revision, if the changes are not modifications under any provisions of 

Title I of the Federal Act and the changes do not exceed the emissions allowable under the 

Permit (whether expressed therein as a rate of emissions or in terms of total emissions). 

For each such change, the Permittee shall provide the Division and the EPA with written 

notification as required below in advance of the proposed changes and shall obtain any 

Permits required under Rules 391-3-1-.03(1) and (2). The Permittee and the Division shall 

attach each such notice to their copy of this Permit. 

[391-3-1-.03(10)(b)5 and 40 CFR 70.4(b)(12)(i)] 

a. For each such change, the Permittee’s written notification and application for a 

construction Permit shall be submitted well in advance of any critical date (typically 

at least 3 months in advance of any commencement of construction, Permit issuance 

date, etc.) involved in the change, but no less than seven (7) days in advance of such 

change and shall include a brief description of the change within the Permitted 

facility, the date on which the change is proposed to occur, any change in emissions, 

and any Permit term or condition that is no longer applicable as a result of the change. 

b. The Permit shield described in Condition 8.16.1 shall not apply to any change made 

pursuant to this condition. 

7.2 Off-Permit Changes 

7.2.1 The Permittee may make changes that are not addressed or prohibited by this Permit, other 

than those described in Condition 7.2.2 below, without a Permit revision, provided the 

following requirements are met: 

[391-3-1-.03(10)(b)6 and 40 CFR 70.4(b)(14)] 

a. Each such change shall meet all applicable requirements and shall not violate any 

existing Permit term or condition. 

b. The Permittee must provide contemporaneous written notice to the Division and to 

the EPA of each such change, except for changes that qualify as insignificant under 

Rule 391-3-1-.03(10)(g). Such written notice shall describe each such change, 

including the date, any change in emissions, pollutants emitted, and any applicable 

requirement that would apply as a result of the change. 

c. The change shall not qualify for the Permit shield in Condition 8.16.1. 

d. The Permittee shall keep a record describing changes made at the source that result in 

emissions of a regulated air pollutant subject to an applicable requirement, but not 

otherwise regulated under the Permit, and the emissions resulting from those changes. 

e. The source shall obtain any Permits required under Rules 391-3-1-.03(1) and (2).
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 42 of 65 

7.2.2 The Permittee shall not make, without a Permit revision, any changes that are not addressed 

or prohibited by this Permit, if such changes are subject to any requirements under Title IV 

of the Federal Act or are modifications under any provision of Title I of the Federal Act. 

[Rule 391-3-1-.03(10)(b)7 and 40 CFR 70.4(b)(15)] 

7.3 Alternative Requirements 

[White Paper #2] 

Not Applicable. 

7.4 Insignificant Activities 

(see Attachment B for the list of Insignificant Activities in existence at the facility at the time of 

permit issuance) 

7.5 Temporary Sources 

[391-3-1-.03(10)(d)5 and 40 CFR 70.6(e)] 

Not Applicable. 

7.6 Short-term Activities 

(see Form D5 “Short Term Activities” of the Permit application and White Paper #1) 

7.6.1 The Permittee shall maintain records of the duration and frequency of the following Short 

term Activities: 

a. Sand blasting for maintenance purposes in accordance with Georgia Rule 391-3-1-

.02(2)(n). 

b. Asbestos removal in accordance with Georgia Rule 391-3-1-.02(9)(b)7.

7.7 Compliance Schedule/Progress Reports 

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(4)] 

None applicable. 

7.8 Emissions Trading 

[391-3-1-.03(10)(d)1(ii) and 40 CFR 70.6(a)(10)] 

Not Applicable. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 43 of 65 

7.9 Acid Rain Requirements 

Facility ORIS code: 6257 

Effective: January 1, 2011 through December 31, 2015 

7.9.1 Emissions which exceed any allowances that the permittee lawfully holds under Title IV of 

the 1990 CAAA, or the regulations promulgated thereunder, are expressly prohibited. 

[40 CFR 70.6(a)(4)] 

7.9.2 Permit revisions are not required for increases in emissions that are authorized by 

allowances acquired pursuant to the State’s Acid Rain Program, provided that such 

increases do not require a permit revision under any other applicable requirement. 

[40 CFR 70.6(a)(4)(i)] 

7.9.3 This permit does not place limits on the number of allowances the permittee may hold. 

However, the permittee may not use allowances as a defense to noncompliance with any 

other applicable requirement. 

[40 CFR 70.6(a)(4)(ii)] 

7.9.4 Any allowances held by the permittee shall be accounted for according to the procedures 

established in regulations promulgated under Title IV of the 1990 CAAA. 

[40 CFR 70.6(a)(4)(iii)] 

7.9.5 Each affected unit, with the exceptions specified in 40 CFR 72.9(g)(6), operated in 

accordance with the Acid Rain portion of this permit shall be deemed to be operating in 

compliance with the Acid Rain Program. 

[40 CFR 70.6(f)(3)(iii)] 

7.9.6 Where an applicable requirement is more stringent than an applicable requirement of 

regulations promulgated under Title IV of the 1990 CAAA, both provisions shall be 

incorporated into the permit and shall be enforceable. 

[40 CFR 70.6(a)(1)(ii)]
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 44 of 65 

7.9.7 SO2 Allowance Allocations and NOX Requirements for each affected unit. 

[40 CFR 73 (SO2) and 40 CFR 76 (NOX)] 

 2011 2012 2013 2014 2015 

SO2

Allowances

EMISSION 21121 21121 21121 21121 21121 

UNIT ID 

SG01 

EPA 

ID 

1 

NOX Limit The standard annual average NOX limit for a Phase II tangentially 

fired boiler is 0.40 lb/mmBtu. In lieu of this limit, the Permittee 

may comply with 40 CFR Part 76 by complying with an approved 

Phase II NOX averaging plan as described below.

Pursuant to 40 CFR 76.11, Georgia EPD approves five NOX emissions averaging plans for this unit. 

Each plan is effective for one calendar year for the years 2011, 2012, 2013, 2014 and 2015.

Under each plan, this unit's NOX emissions shall not exceed the annual average alternative 

contemporaneous emission limitation of 0.50 lb/mmBtu. In addition, this unit shall not have an 

annual heat input greater than 71,791,890 mmBtu.

Under the plan, the actual Btu-weighted annual average NOX emission rate for the units in the

plan shall be less than or equal to the Btu-weighted annual average NOX emission rate for the

same units had they each been operated, during the same period of time, in compliance with the 

applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early

election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated 

representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 

76.11(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in 

compliance for that year with its alternative contemporaneous annual emission limitation and annual 

heat input limit.

In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only when

the Mississippi Department of Environmental Quality, the Alabama Department of Environmental 

Management, the Florida Department of Environmental Protection, and the Jefferson County 

Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NOX compliance plan, this unit shall comply with all other applicable 

requirements of 40 CFR part 76, including the duty to reapply for a NOX compliance plan and 

requirements covering excess emissions.
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 45 of 65 

 2011 2012 2013 2014 2015 

SO2

Allowances

EMISSION 21270 21270 21270 21270 21270 

UNIT ID 

SG02 

EPA 

ID 

2 

NOX Limit The standard annual average NOX limit for a Phase II tangentially 

fired boiler is 0.40 lb/mmBtu. In lieu of this limit, the Permittee 

may comply with 40 CFR Part 76 by complying with an approved 

Phase II NOX averaging plan as described below.

Pursuant to 40 CFR 76.11, Georgia EPD approves five NOX emissions averaging plans for this unit. 

Each plan is effective for one calendar year for the years 2011, 2012, 2013, 2014, and 2015.

Under each plan, this unit's NOX emissions shall not exceed the annual average alternative 

contemporaneous emission limitation of 0.50 lb/mmBtu. In addition, this unit shall not have an 

annual heat input greater than 71,474,044 mmBtu.

Under the plan, the actual Btu-weighted annual average NOX emission rate for the units in the

plan shall be less than or equal to the Btu-weighted annual average NOX emission rate for the

same units had they each been operated, during the same period of time, in compliance with the 

applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early

election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated 

representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 

76.11(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in 

compliance for that year with its alternative contemporaneous annual emission limitation and annual 

heat input limit.

In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only when

the Mississippi Department of Environmental Quality, the Alabama Department of Environmental 

Management, the Florida Department of Environmental Protection, and the Jefferson County 

Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NOX compliance plan, this unit shall comply with all other applicable 

requirements of 40 CFR part 76, including the duty to reapply for a NOX compliance plan and 

requirements covering excess emissions.
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 46 of 65 

 2011 2012 2013 2014 2015 

SO2

Allowances

EMISSION 21304 21304 21304 21304 21304 

UNIT ID 

SG03 

EPA 

ID 

3 

NOX Limit The standard annual average NOX limit for a Phase I tangentially 

fired boiler is 0.45 lb/mmBtu. In lieu of this limit, the Permittee 

may comply with 40 CFR Part 76 by complying with an approved 

Phase II NOX averaging plan as described below.

Pursuant to 40 CFR 76.11, Georgia EPD approves five NOX emissions averaging plans for this unit. 

Each plan is effective for one calendar year for the years 2011, 2012, 2013, 2014, and 2015.

Under each plan, this unit's NOX emissions shall not exceed the annual average alternative 

contemporaneous emission limitation of 0.29 lb/mmBtu. In addition, this unit shall not have an 

annual heat input less than 53,390,136 mmBtu.

Under the plan, the actual Btu-weighted annual average NOX emission rate for the units in the

plan shall be less than or equal to the Btu-weighted annual average NOX emission rate for the

same units had they each been operated, during the same period of time, in compliance with the 

applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early

election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated 

representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 

76.11(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in 

compliance for that year with its alternative contemporaneous annual emission limitation and annual 

heat input limit.

In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only when

the Mississippi Department of Environmental Quality, the Alabama Department of Environmental 

Management, the Florida Department of Environmental Protection, and the Jefferson County 

Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NOX compliance plan, this unit shall comply with all other applicable 

requirements of 40 CFR part 76, including the duty to reapply for a NOX compliance plan and 

requirements covering excess emissions.
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 47 of 65 

 2011 2012 2013 2014 2015 

SO2

Allowances

EMISSION 21280 21280 21280 21280 21280 

UNIT ID 

SG04 

EPA 

ID 

4 

NOX Limit The standard annual average NOX limit for a Phase II tangentially 

fired boiler is 0.40 lb/mmBtu. In lieu of this limit, the Permittee 

may comply with 40 CFR Part 76 by complying with an approved 

Phase II NOX averaging plan as described below.

Pursuant to 40 CFR 76.11, Georgia EPD approves five NOX emissions averaging plans for this unit. 

Each plan is effective for one calendar year for the years 2011, 2012, 2013, 2014, and 2015.

Under each plan, this unit's NOX emissions shall not exceed the annual average alternative 

contemporaneous emission limitation of 0.30 lb/mmBtu. In addition, this unit shall not have an 

annual heat input less than 53,390,136 mmBtu.

Under the plan, the actual Btu-weighted annual average NOX emission rate for the units in the

plan shall be less than or equal to the Btu-weighted annual average NOX emission rate for the

same units had they each been operated, during the same period of time, in compliance with the 

applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early

election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated 

representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 

76.11(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in 

compliance for that year with its alternative contemporaneous annual emission limitation and annual 

heat input limit.

In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only when

the Mississippi Department of Environmental Quality, the Alabama Department of Environmental 

Management, the Florida Department of Environmental Protection, and the Jefferson County 

Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NOX compliance plan, this unit shall comply with all other applicable 

requirements of 40 CFR part 76, including the duty to reapply for a NOX compliance plan and 

requirements covering excess emissions.

Note: The number of allowances allocated to Phase II affected units by U.S. EPA may change as 

a result of revisions to 40 CFR Part 73. In addition, the number of allowances actually held 

by an affected source in a unit account may differ from the number allocated by U.S. EPA. 

Neither of the aforementioned conditions necessitates a revision to the unit SO2 allowance 

allocations identified in this permit (See CFR 72.84).

7.9.8 Permit Application: The Phase II Acid Rain Permit Application, Compliance Plan, and 

NOX Averaging Plan submitted for this source, as corrected by the State of Georgia, is 

attached as part of this Permit. The owners and operators of the source must comply with 

the standard requirements and special provisions set forth in the application. 

[40 CFR 72.50(a)(1)]
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 48 of 65 

7.10 Prevention of Accidental Releases (Section 112(r) of the 1990 CAAA) 

[391-3-1-.02(10)] 

7.10.1 When and if the requirements of 40 CFR Part 68 become applicable, the Permittee shall 

comply with all applicable requirements of 40 CFR Part 68, including the following. 

a. The Permittee shall submit a Risk Management Plan (RMP) as provided in 40 CFR 

68.150 through 68.185. The RMP shall include a registration that reflects all covered 

processes. 

b. For processes eligible for Program 1, as provided in 40 CFR 68.10, the Permittee 

shall comply with 7.10.1.a. and the following additional requirements: 

i. Analyze the worst-case release scenario for the process(es), as provided in 40 

CFR 68.25; document that the nearest public receptor is beyond the distance to 

a toxic or flammable endpoint defined in 40 CFR 68.22(a); and submit in the 

RMP the worst-case release scenario as provided in 40 CFR 68.165. 

ii. Complete the five-year accident history for the process as provided in 40 CFR 

68.42 and submit in the RMP as provided in 40 CFR 68.168 

iii. Ensure that response actions have been coordinated with local emergency 

planning and response agencies 

iv. Include a certification in the RMP as specified in 40 CFR 68.12(b)(4) 

c. For processes subject to Program 2, as provided in 40 CFR 68.10, the Permittee shall 

comply with 7.10.1.a., 7.10.1.b. and the following additional requirements: 

i. Develop and implement a management system as provided in 40 CFR 68.15 

ii. Conduct a hazard assessment as provided in 40 CFR 68.20 through 68.42 

iii. Implement the Program 2 prevention steps provided in 40 CFR 68.48 through 

68.60 or implement the Program 3 prevention steps provided in 40 CFR 68.65 

through 68.87 

iv. Develop and implement an emergency response program as provided in 40 CFR 

68.90 through 68.95 

v. Submit as part of the RMP the data on prevention program elements for 

Program 2 processes as provided in 40 CFR 68.170 

d. For processes subject to Program 3, as provided in 40 CFR 68.10, the Permittee shall 

comply with 7.10.1.a., 7.10.1.b. and the following additional requirements: 

i. Develop and implement a management system as provided in 40 CFR 68.15 

ii. Conduct a hazard assessment as provided in 40 CFR 68.20 through 68.42 

iii. Implement the prevention requirements of 40 CFR 68.65 through 68.87 

iv. Develop and implement an emergency response program as provided in 40 CFR 

68.90 through 68.95 

v. Submit as part of the RMP the data on prevention program elements for 

Program 3 as provided in 40 CFR 68.175 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 49 of 65 

e. All reports and notification required by 40 CFR Part 68 must be submitted 

electronically using RMP*eSubmit (information for establishing an account can be 

found at www.epa.gov/emergencies/content/rmp/rmp_esubmit.htm). Electronic 

Signature Agreements should be mailed to: 

MAIL 

Risk Management Program (RMP) Reporting Center 

P.O. Box 10162 

Fairfax, VA 22038 

COURIER & FEDEX 

Risk Management Program (RMP) Reporting Center 

CGI Federal 

12601 Fair Lakes Circle 

Fairfax, VA 22033 

Compliance with all requirements of this condition, including the registration and 

submission of the RMP, shall be included as part of the compliance certification submitted 

in accordance with Condition 8.14.1. 

7.11 Stratospheric Ozone Protection Requirements (Title VI of the CAAA of 1990) 

7.11.1 If the Permittee performs any of the activities described below or as otherwise defined in 40 

CFR Part 82, the Permittee shall comply with the standards for recycling and emissions 

reduction pursuant to 40 CFR Part 82, Subpart F, except as provided for motor vehicle air 

conditioners (MVACs) in Subpart B: 

a. Persons opening appliances for maintenance, service, repair, or disposal must comply 

with the required practices pursuant to 40 CFR 82.156. 

b. Equipment used during the maintenance, service, repair, or disposal of appliance must 

comply with the standards for recycling and recovery equipment pursuant to 40 CFR 

82.158. 

c. Persons performing maintenance, service, repair, or disposal of appliances must be 

certified by an approved technician certification program pursuant to 40 CFR 82.161. 

d. Persons disposing of small appliances, MVACs, and MVAC-like appliances must 

comply with record keeping requirements pursuant to 40 CFR 82.166. 

[Note: “MVAC-like appliance” is defined in 40 CFR 82.152.] 

e. Persons owning commercial or industrial process refrigeration equipment must 

comply with the leak repair requirements pursuant to 40 CFR 82.156. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 50 of 65 

f. Owners/operators of appliances normally containing 50 or more pounds of refrigerant 

must keep records of refrigerant purchased and added to such appliances pursuant to 

40 CFR 82.166. 

 

7.11.2 If the Permittee performs a service on motor (fleet) vehicles and if this service involves an 

ozone-depleting substance (refrigerant) in the MVAC, the Permittee is subject to all the 

applicable requirements as specified in 40 CFR Part 82, Subpart B, Servicing of Motor 

Vehicle Air Conditioners. 

The term “motor vehicle” as used in Subpart B does not include a vehicle in which final 

assembly of the vehicle has not been completed. The term “MVAC” as used in Subpart B 

does not include air-tight sealed refrigeration systems used for refrigerated cargo, or air 

conditioning systems on passenger buses using HCFC-22 refrigerant. 

7.12 Revocation of Existing Permits and Amendments 

The following Air Quality Permits, Amendments, and 502(b)10 are subsumed by this permit and are 

hereby revoked: 

Air Quality Permit and Amendment Number(s) Dates of Original Permit or Amendment Issuance 

4911-207-0008-V-02-0 11/15/2005 

4911-207-0008-V-02-1 12/12/2006 

4911-207-0008-V-02-2 3/7/2007 

4911-207-0008-V-02-3 9/17/2008 

4911-207-0008-V-02-4 12/2/2008 

4911-207-0008-V-02-5 3/12/2009 

4911-207-0008-V-02-6 5/29/2009 

4911-207-0008-V-02-7 11/16/2009 

4911-207-0008-V-02-8 9/17/2009 

4911-207-0008-V-02-A 2/23/2010 

4911-207-0008-V-02-B 5/12/2010 

4911-207-0008-V-02-C 11/23/2010 

7.13 Pollution Prevention 

None applicable. 

7.14 Specific Conditions 

None applicable. 

7.15 Clean Air Interstate Rule (CAIR) Requirements 

[40 CFR 96, 391-3-1-.02(12), 391-3-1-.02(13)] 

7.15.1 Permit Application: The CAIR Permit Application, as corrected by the State of Georgia, is 

attached as part of this Permit. The owners and operators of these CAIR units as identified 

in Condition 7.15.2 must comply with the standard requirements and special provisions set 

forth in the application. 

[40 CFR 96.121, 96.122, 96.221, 96.222, 96.321, and 96.322] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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7.15.2 The owners and operators of the source shall comply with the Annual NOX Allowance 

Allocations in accordance with the CAIR requirements as follows: 

[40 CFR 96, 391-3-1-.02(12)] 

 

2012 2013 

Facility 

Wide 

Emission 

Unit IDs. 

SG01 

SG02 

SG03 

SG04 

EPA 

IDs. 

1 

2 

3 

4 

CAIR 

Facility Wide 

Annual NOX

Allowances 

(tpy) 

17377 17377 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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PART 8.0 GENERAL PROVISIONS 

8.1 Terms and References 

8.1.1 Terms not otherwise defined in the Permit shall have the meaning assigned to such terms in 

the referenced regulation. 

8.1.2 Where more than one condition in this Permit applies to an emission unit and/or the entire 

facility, each condition shall apply and the most stringent condition shall take precedence. 

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

8.2 EPA Authorities 

8.2.1 Except as identified as “State-only enforceable” requirements in this Permit, all terms and 

conditions contained herein shall be enforceable by the EPA and citizens under the Clean 

Air Act, as amended, 42 U.S.C. 7401, et seq. 

[40 CFR 70.6(b)(1)] 

8.2.2 Nothing in this Permit shall alter or affect the authority of the EPA to obtain information 

pursuant to 42 U.S.C. 7414, “Inspections, Monitoring, and Entry.” 

[40 CFR 70.6(f)(3)(iv)] 

8.2.3 Nothing in this Permit shall alter or affect the authority of the EPA to impose emergency 

orders pursuant to 42 U.S.C. 7603, “Emergency Powers.” 

[40 CFR 70.6(f)(3)(i)] 

8.3 Duty to Comply 

8.3.1 The Permittee shall comply with all conditions of this operating Permit. Any Permit 

noncompliance constitutes a violation of the Federal Clean Air Act and the Georgia Air 

Quality Act and/or State rules and is grounds for enforcement action; for Permit 

termination, revocation and reissuance, or modification; or for denial of a Permit renewal 

application. Any noncompliance with a Permit condition specifically designated as 

enforceable only by the State constitutes a violation of the Georgia Air Quality Act and/or 

State rules only and is grounds for enforcement action; for Permit termination, revocation 

and reissuance, or modification; or for denial of a Permit renewal application. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(i)] 

8.3.2 The Permittee shall not use as a defense in an enforcement action the contention that it 

would have been necessary to halt or reduce the Permitted activity in order to maintain 

compliance with the conditions of this Permit. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(ii)] 

8.3.3 Nothing in this Permit shall alter or affect the liability of the Permittee for any violation of 

applicable requirements prior to or at the time of Permit issuance. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(f)(3)(ii)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 53 of 65 

8.3.4 Issuance of this Permit does not relieve the Permittee from the responsibility of obtaining 

any other permits, licenses, or approvals required by the Director or any other federal, state, 

or local agency. 

[391-3-1-.03(10)(e)1(iv) and 40 CFR 70.7(a)(6)] 

8.4 Fee Assessment and Payment 

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

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

Permit Fees.” 

[391-3-1-.03(9)] 

8.5 Permit Renewal and Expiration 

8.5.1 This Permit shall remain in effect for five (5) years from the effective date. The Permit 

shall become null and void after the expiration date unless a timely and complete renewal 

application has been submitted to the Division at least six (6) months, but no more than 

eighteen (18) months prior to the expiration date of the Permit. 

[391-3-1-.03(10)(d)1(i), (e)2, and (e)3(ii) and 40 CFR 70.5(a)(1)(iii)] 

8.5.2 Permits being renewed are subject to the same procedural requirements, including those for 

public participation and affected State and EPA review, that apply to initial Permit 

issuance. 

[391-3-1-.03(10)(e)3(i)] 

8.5.3 Notwithstanding the provisions in 8.5.1 above, if the Division has received a timely and 

complete application for renewal, deemed it administratively complete, and failed to reissue 

the Permit for reasons other than cause, authorization to operate shall continue beyond the 

expiration date to the point of Permit modification, reissuance, or revocation. 

[391-3-1-.03(10)(e)3(iii)] 

8.6 Transfer of Ownership or Operation 

8.6.1 This Permit is not transferable by the Permittee. Future owners and operators shall obtain a 

new Permit from the Director. The new Permit may be processed as an administrative 

amendment if no other change in this Permit is necessary, and provided that a written 

agreement containing a specific date for transfer of Permit responsibility coverage and 

liability between the current and new Permittee has been submitted to the Division at least 

thirty (30) days in advance of the transfer. 

[391-3-1-.03(4)] 

 

8.7 Property Rights 

8.7.1 This Permit shall not convey property rights of any sort, or any exclusive privileges. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(iv)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 54 of 65 

8.8 Submissions 

8.8.1 Reports, test data, monitoring data, notifications, annual certifications, and requests for 

revision and renewal shall be submitted to: 

Georgia Department of Natural Resources 

Environmental Protection Division 

Air Protection Branch 

Atlanta Tradeport, Suite 120 

4244 International Parkway 

Atlanta, Georgia 30354-3908 

8.8.2 Any records, compliance certifications, and monitoring data required by the provisions in 

this Permit to be submitted to the EPA shall be sent to: 

Air and EPCRA Enforcement Branch – U. S. EPA Region 4 

Sam Nunn Atlanta Federal Center 

61 Forsyth Street, SW 

Atlanta, Georgia 30303-3104 

8.8.3 Any application form, report, or compliance certification submitted pursuant to this Permit 

shall contain a certification by a responsible official of its truth, accuracy, and 

completeness. This certification shall state that, based on information and belief formed 

after reasonable inquiry, the statements and information in the document are true, accurate, 

and complete. 

[391-3-1-.03(10)(c)2, 40 CFR 70.5(d) and 40 CFR 70.6(c)(1)] 

8.8.4 Unless otherwise specified, all submissions under this permit shall be submitted to the 

Division only. 

8.9 Duty to Provide Information 

8.9.1 The Permittee, upon becoming aware that any relevant facts were omitted or incorrect 

information was submitted in the Permit application, shall promptly submit such 

supplementary facts or corrected information to the Division. 

[391-3-1-.03(10)(c)5] 

 

8.9.2 The Permittee shall furnish to the Division, in writing, information that the Division may 

request to determine whether cause exists for modifying, revoking and reissuing, or 

terminating the Permit, or to determine compliance with the Permit. Upon request, the 

Permittee shall also furnish to the Division copies of records that the Permittee is required 

to keep by this Permit or, for information claimed to be confidential, the Permittee may 

furnish such records directly to the EPA, if necessary, along with a claim of confidentiality. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(v)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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8.10 Modifications 

8.10.1 Prior to any source commencing a modification as defined in 391-3-1-.01(pp) that may 

result in air pollution and not exempted by 391-3-1-.03(6), the Permittee shall submit a 

Permit application to the Division. The 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. 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. 

[391-3-1-.03(1) through (8)] 

8.11 Permit Revision, Revocation, Reopening and Termination 

8.11.1 This Permit may be revised, revoked, reopened and reissued, or terminated for cause by the 

Director. The Permit will be reopened for cause and revised accordingly under the 

following circumstances: 

[391-3-1-.03(10)(d)1(i)] 

a. If additional applicable requirements become applicable to the source and the 

remaining Permit term is three (3) years or longer. In this case, the reopening shall be 

completed no later than eighteen (18) months after promulgation of the applicable 

requirement. A reopening shall not be required if compliance with the applicable 

requirement is not required until after the date on which the Permit is due to expire; 

[391-3-1-.03(10)(e)6(i)(I)] 

b. If any additional applicable requirements of the Acid Rain Program become 

applicable to the source; 

[391-3-1-.03(10)(e)6(i)(II)] (Acid Rain sources only) 

c. The Director determines that the Permit contains a material mistake or inaccurate 

statements were made in establishing the emissions standards or other terms or 

conditions of the Permit; or 

[391-3-1-.03(10)(e)6(i)(III) and 40 CFR 70.7(f)(1)(iii)] 

d. The Director determines that the Permit must be revised or revoked to assure 

compliance with the applicable requirements. 

[391-3-1-.03(10)(e)6(i)(IV) and 40 CFR 70.7(f)(1)(iv)] 

8.11.2 Proceedings to reopen and reissue a Permit shall follow the same procedures as applicable 

to initial Permit issuance and shall affect only those parts of the Permit for which cause to 

reopen exists. Reopenings shall be made as expeditiously as practicable. 

[391-3-1-.03(10)(e)6(ii)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 56 of 65 

8.11.3 Reopenings shall not be initiated before a notice of intent to reopen is provided to the 

source by the Director at least thirty (30) days in advance of the date the Permit is to be 

reopened, except that the Director may provide a shorter time period in the case of an 

emergency. 

[391-3-1-.03(10)(e)6(iii)] 

8.11.4 All Permit conditions remain in effect until such time as the Director takes final action. 

The filing of a request by the Permittee for any Permit revision, revocation, reissuance, or 

termination, or of a notification of planned changes or anticipated noncompliance, shall not 

stay any Permit condition. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(iii)] 

8.11.5 A Permit revision shall not be required for changes that are explicitly authorized by the 

conditions of this Permit. 

8.11.6 A Permit revision shall not be required for changes that are part of an approved economic 

incentive, marketable Permit, emission trading, or other similar program or process for 

change which is specifically provided for in this Permit. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(8)] 

8.12 Severability 

8.12.1 Any condition or portion of this Permit which is challenged, becomes suspended or is ruled 

invalid as a result of any legal or other action shall not invalidate any other portion or 

condition of this Permit. 

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(5)] 

 

8.13 Excess Emissions Due to an Emergency 

8.13.1 An “emergency” means any situation arising from sudden and reasonably unforeseeable 

events beyond the control of the source, including acts of God, which situation requires 

immediate corrective action to restore normal operation, and that causes the source to 

exceed a technology-based emission limitation under the Permit, due to unavoidable 

increases in emissions attributable to the emergency. An emergency shall not include 

noncompliance to the extent caused by improperly designed equipment, lack of 

preventative maintenance, careless or improper operation, or operator error. 

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(1)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 57 of 65 

8.13.2 An emergency shall constitute an affirmative defense to an action brought for 

noncompliance with the technology-based emission limitations if the Permittee 

demonstrates, through properly signed contemporaneous operating logs or other relevant 

evidence, that: 

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(2) and (3)] 

a. An emergency occurred and the Permittee can identify the cause(s) of the emergency; 

b. The Permitted facility was at the time of the emergency being properly operated; 

c. During the period of the emergency, the Permittee took all reasonable steps to 

minimize levels of emissions that exceeded the emissions standards, or other 

requirements in the Permit; and 

d. The Permittee promptly notified the Division and submitted written notice of the 

emergency to the Division within two (2) working days of the time when emission 

limitations were exceeded due to the emergency. This notice must contain a 

description of the emergency, any steps taken to mitigate emissions, and corrective 

actions taken. 

8.13.3 In an enforcement proceeding, the Permittee seeking to establish the occurrence of an 

emergency shall have the burden of proof. 

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(4)] 

8.13.4 The emergency conditions listed above are in addition to any emergency or upset 

provisions contained in any applicable requirement. 

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(5)] 

 

8.14 Compliance Requirements 

8.14.1 Compliance Certification 

The Permittee shall provide written certification to the Division and to the EPA, at least 

annually, of compliance with the conditions of this Permit. The annual written certification 

shall be postmarked no later than February 28 of each year and shall be submitted to the 

Division and to the EPA. The certification shall include, but not be limited to, the 

following elements: 

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(5)] 

a. The identification of each term or condition of the Permit that is the basis of the 

certification; 
Title V Permit 

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Page 58 of 65 

b. The status of compliance with the terms and conditions of the permit for the period 

covered by the certification, including whether compliance during the period was 

continuous or intermittent, based on the method or means designated in paragraph c 

below. The certification shall identify each deviation and take it into account in the 

compliance certification. The certification shall also identify as possible exceptions 

to compliance any periods during which compliance is required and in which an 

excursion or exceedance as defined under 40 CFR Part 64 occurred; 

c. The identification of the method(s) or other means used by the owner or operator for 

determining the compliance status with each term and condition during the 

certification period; 

d. Any other information that must be included to comply with section 113(c)(2) of the 

Act, which prohibits knowingly making a false certification or omitting material 

information; and 

e. Any additional requirements specified by the Division. 

8.14.2 Inspection and Entry 

a. Upon presentation of credentials and other documents as may be required by law, the 

Permittee shall allow authorized representatives of the Division to perform the 

following: 

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(2)] 

i. Enter upon the Permittee's premises where a Part 70 source is located or an 

emissions-related activity is conducted, or where records must be kept under the 

conditions of this Permit; 

ii. Have access to and copy, at reasonable times, any records that must be kept 

under the conditions of this Permit; 

iii. Inspect at reasonable times any facilities, equipment (including monitoring and 

air pollution control equipment), practices, or operations regulated or required 

under this Permit; and 

iv. Sample or monitor any substances or parameters at any location during 

operating hours for the purpose of assuring Permit compliance or compliance 

with applicable requirements as authorized by the Georgia Air Quality Act. 

b. No person shall obstruct, hamper, or interfere with any such authorized representative 

while in the process of carrying out his official duties. Refusal of entry or access may 

constitute grounds for Permit revocation and assessment of civil penalties.[391-3-1-

.07 and 40 CFR 70.11(a)(3)(i)] 

8.14.3 Schedule of Compliance 

a. For applicable requirements with which the Permittee is in compliance, the Permittee 

shall continue to comply with those requirements. 

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(A)] 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

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b. For applicable requirements that become effective during the Permit term, the 

Permittee shall meet such requirements on a timely basis unless a more detailed 

schedule is expressly required by the applicable requirement. 

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(B)] 

c. Any schedule of compliance for applicable requirements with which the source is not 

in compliance at the time of Permit issuance shall be supplemental to, and shall not 

sanction noncompliance with, the applicable requirements on which it is based. 

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(C)] 

8.14.4 Excess Emissions

 

a. Excess emissions resulting from startup, shutdown, or 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 Chapter 391-3-1 of the Georgia Rules for Air Quality Control.

[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)] 

8.15 Circumvention 

State Only Enforceable Condition.

8.15.1 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 

which is based on the concentration of the pollutants in the gases discharged into the 

atmosphere. 

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

 
Title V Permit 

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8.16 Permit Shield 

8.16.1 Compliance with the terms of this Permit shall be deemed compliance with all applicable 

requirements as of the date of Permit issuance provided that all applicable requirements are 

included and specifically identified in the Permit. 

[391-3-1-.03(10)(d)6] 

8.16.2 Any Permit condition identified as “State only enforceable” does not have a Permit shield. 

8.17 Operational Practices 

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

maintain and operate the 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 any information available to the Division that may include, but is not 

limited to, monitoring results, observations of the opacity or other characteristics of 

emissions, review of operating and maintenance procedures or records, and inspection or 

surveillance of the source. 

[391-3-1-.02(2)(a)10] 

State Only Enforceable Condition. 

8.17.2 No person owning, leasing, or controlling, the operation of any air contaminant sources 

shall willfully, negligently or through failure to provide necessary equipment or facilities or 

to take necessary precautions, cause, permit, or allow the emission from said air 

contamination source or sources, of such quantities of air contaminants as will cause, or 

tend to cause, by themselves, or in conjunction with other air contaminants, a condition of 

air pollution in quantities or characteristics or of a duration which is injurious or which 

unreasonably interferes with the enjoyment of life or use of property in such area of the 

State as is affected thereby. Complying with Georgia’s Rules for Air Quality Control 

Chapter 391-3-1 and Conditions in this Permit, shall in no way exempt a person from this 

provision. 

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

8.18 Visible Emissions 

8.18.1 Except as may be provided in other provisions of this Permit, the Permittee shall not cause, 

let, suffer, permit or allow emissions from any air contaminant source the opacity of which 

is equal to or greater than forty (40) percent. 

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

8.19 Fuel-burning Equipment 

8.19.1 The Permittee shall not cause, let, suffer, permit, or allow the emission of fly ash and/or 

other particulate matter from any fuel-burning equipment with rated heat input capacity of 

less than 10 million Btu per hour, in operation or under construction on or before January 1, 

1972 in amounts equal to or exceeding 0.7 pounds per million BTU heat input. 

[391-3-1-.02(2)(d)] 
Title V Permit 

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Page 61 of 65 

8.19.2 The Permittee shall not cause, let, suffer, permit, or allow the emission of fly ash and/or 

other particulate matter from any fuel-burning equipment with rated heat input capacity of 

less than 10 million Btu per hour, constructed after January 1, 1972 in amounts equal to or 

exceeding 0.5 pounds per million BTU heat input. 

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

8.19.3 The Permittee shall not cause, let, suffer, permit, or allow the emission from any fuelburning equipment constructed or extensively modified after January 1, 1972, visible 

emissions the opacity of which is equal to or greater than twenty (20) percent except for 

one six minute period per hour of not more than twenty-seven (27) percent opacity. 

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

8.20 Sulfur Dioxide 

8.20.1 Except as may be specified in other provisions of this Permit, the Permittee shall not burn 

fuel containing more than 2.5 percent sulfur, by weight, in any fuel burning source that has 

a heat input capacity below 100 million Btu's per hour. 

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

8.21 Particulate Emissions 

8.21.1 Except as may be specified in other provisions of this Permit, the Permittee shall not cause, 

let, permit, suffer, or allow the rate of emission from any source, particulate matter in total 

quantities equal to or exceeding the allowable rates shown below. Equipment in operation, 

or under construction contract, on or before July 2, 1968, shall be considered existing 

equipment. All other equipment put in operation or extensively altered after said date is to 

be considered new equipment. 

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

a. The following equations shall be used to calculate the allowable rates of emission 

from new equipment: 

E = 4.1P0.67; for process input weight rate up to and including 30 tons per hour. 

E = 55P0.11 - 40; for process input weight rate above 30 tons per hour. 

b. The following equation shall be used to calculate the allowable rates of emission from 

existing equipment: 

 E = 4.1P0.67

In the above equations, E = emission rate in pounds per hour, and 

P = process input weight rate in tons per hour. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 62 of 65 

8.22 Fugitive Dust 

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

8.22.1 Except as may be specified in other provisions of this Permit, the Permittee shall take all 

reasonable precautions to prevent dust from any operation, process, handling, transportation 

or storage facility from becoming airborne. Reasonable precautions that could be taken to 

prevent dust from becoming airborne include, but are not limited to, the following: 

a. Use, where possible, of water or chemicals for control of dust in the demolition of 

existing buildings or structures, construction operations, the grading of roads or the 

clearing of land; 

b. Application of asphalt, water, or suitable chemicals on dirt roads, materials, 

stockpiles, and other surfaces that can give rise to airborne dusts; 

c. Installation and use of hoods, fans, and fabric filters to enclose and vent the handling 

of dusty materials. Adequate containment methods can be employed during 

sandblasting or other similar operations; 

d. Covering, at all times when in motion, open bodied trucks transporting materials 

likely to give rise to airborne dusts; and 

e. The prompt removal of earth or other material from paved streets onto which earth or 

other material has been deposited. 

8.22.2 The opacity from any fugitive dust source shall not equal or exceed 20 percent. 

8.23 Solvent Metal Cleaning 

8.23.1 Except as may be specified in other provisions of this Permit, the Permittee shall not cause, 

suffer, allow, or permit the operation of a cold cleaner degreaser unless the following 

requirements for control of emissions of the volatile organic compounds are satisfied: 

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

a. The degreaser shall be equipped with a cover to prevent escape of VOC during 

periods of non-use, 

b. The degreaser shall be equipped with a device to drain cleaned parts before removal 

from the unit, 

c. If the solvent volatility is 0.60 psi or greater measured at 100 oF, or if the solvent is 

heated above 120 oF, then one of the following control devices must be used: 

i. The degreaser shall be equipped with a freeboard that gives a freeboard ratio of 

0.7 or greater, or 

ii. The degreaser shall be equipped with a water cover (solvent must be insoluble 

in and heavier than water), or 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 63 of 65 

iii. The degreaser shall be equipped with a system of equivalent control, including 

but not limited to, a refrigerated chiller or carbon adsorption system. 

d. Any solvent spray utilized by the degreaser must be in the form of a solid, fluid 

stream (not a fine, atomized or shower type spray) and at a pressure which will not 

cause excessive splashing, and 

e. All waste solvent from the degreaser shall be stored in covered containers and shall 

not be disposed of by such a method as to allow excessive evaporation into the 

atmosphere. 

8.24 Incinerators 

8.24.1 Except as specified in the section dealing with conical burners, no person shall cause, let, 

suffer, permit, or allow the emissions of fly ash and/or other particulate matter from any 

incinerator, in amounts equal to or exceeding the following: 

 [391-3-1-.02(2)(c)1-4] 

a. Units with charging rates of 500 pounds per hour or less of combustible waste, 

including water, shall not emit fly ash and/or particulate matter in quantities 

exceeding 1.0 pound per hour. 

b. Units with charging rates in excess of 500 pounds per hour of combustible waste, 

including water, shall not emit fly ash and/or particulate matter in excess of 0.20 

pounds per 100 pounds of charge. 

8.24.2 No person shall cause, let, suffer, permit, or allow from any incinerator, visible emissions 

the opacity of which is equal to or greater than twenty (20) percent except for one six 

minute period per hour of not more than twenty-seven (27) percent opacity. 

8.24.3 No person shall cause or allow particles to be emitted from an incinerator which are 

individually large enough to be visible to the unaided eye. 

8.24.4 No person shall operate an existing incinerator unless: 

a. It is a multiple chamber incinerator; 

b. It is equipped with an auxiliary burner in the primary chamber for the purpose of 

creating a pre-ignition temperature of 800o

F; and 

c. It has a secondary burner to control smoke and/or odors and maintain a temperature 

of at least 1500o

F in the secondary chamber. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 64 of 65 

8.25 Volatile Organic Liquid Handling and Storage 

8.25.1 The Permittee shall ensure that each storage tank subject to the requirements of Rule 391-3-

1-.02(2)(vv) “Volatile Organic Liquid Handling and Storage” is equipped with submerged 

fill pipes. For the purposes of this condition and the permit, a submerged fill pipe is 

defined as any fill pipe with a discharge opening which is within six inches of the tank 

bottom. 

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

8.26 Use of Any Credible Evidence or Information 

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

this permit, for the purpose of submission of compliance certifications or 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. 

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

8.27 Diesel-Fired Internal Combustion Engines 

8.27.1 The Permittee shall comply with all applicable provisions of New Source Performance 

Standards (NSPS) Federal Rule 40 CFR Part 60 Subpart A-"General Provisions" and 

Subpart IIII-“Standards for Stationary Compression Ignition Internal Combustion Engines,” 

for diesel-fired internal combustion engine(s) manufactured after April 1, 2006 or 

modified/reconstructed after July 11, 2005. Such requirements include but are not limited 

to: 

[40 CFR 60.4205(b), 391-3-1-.02(8)(b)77 ] 

a. Equip all emergency generator engines with non-resettable hour meters 

b. Purchase only diesel fuel with a maximum sulfur content of 15 ppm unless otherwise 

specified by the Division. 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Page 65 of 65 

Attachments 

A. List of Standard Abbreviations and List of Permit Specific Abbreviations 

B. Insignificant Activities Checklist, Insignificant Activities Based on Emission Levels and Generic 

Emission Groups 

C. List of References 

D. U.S. EPA Acid Rain Program Permit Application for Phase II NOX Averaging Plan 

E. CAIR Permit Application for SO2 and NOX Annual Trading Programs 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 1 of 8 

ATTACHMENT A 

List Of Standard Abbreviations 

AIRS Aerometric Information Retrieval System PM Particulate Matter 

APCD Air Pollution Control Device PM10

(PM10) 

Particulate Matter less than 10 micrometers in 

diameter 

ASTM American Society for Testing and Materials PPM (ppm) Parts per Million 

BACT Best Available Control Technology PSD Prevention of Significant Deterioration 

BTU British Thermal Unit RACT Reasonably Available Control Technology 

CAAA Clean Air Act Amendments RMP Risk Management Plan 

CEMS Continuous Emission Monitoring System SIC Standard Industrial Classification 

CERMS Continuous Emission Rate Monitoring System SIP State Implementation Plan 

CFR Code of Federal Regulations SO2 (SO2) Sulfur Dioxide 

CMS Continuous Monitoring System(s) USC United States Code 

CO Carbon Monoxide VE Visible Emissions 

COMS Continuous Opacity Monitoring System VOC Volatile Organic Compound 

dscf/dscm Dry Standard Cubic Foot / Dry Standard Cubic 

Meter 

 

EPA United States Environmental Protection Agency 

EPCRA Emergency Planning and Community Right to 

Know Act 

 

gr Grain(s) 

GPM (gpm) Gallons per minute 

H2O (H2O) Water 

HAP Hazardous Air Pollutant 

HCFC Hydro-chloro-fluorocarbon 

MACT Maximum Achievable Control Technology 

MMBtu Million British Thermal Units 

MMBtu/hr Million British Thermal Units per hour 

MVAC Motor Vehicle Air Conditioner 

MW Megawatt 

NESHAP National Emission Standards for Hazardous Air 

Pollutants 

 

NOx (NOx) Nitrogen Oxides 

NSPS New Source Performance Standards 

OCGA Official Code of Georgia Annotated 

List of Permit Specific Abbreviations 

PAC Powdered Activated Carbon FGD Flue Gas Desulfurization 

ESP Electrostatic Precipitator SCR Selective Catalytic Reduction 

PCB Polychlorinated Biphenyl 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 2 of 8 

ATTACHMENT B 

NOTE: Attachment B contains information regarding insignificant emission units/activities and groups of generic emission 

units/activities in existence at the facility at the time of Permit issuance. Future modifications or additions of insignificant 

emission units/activities and equipment that are part of generic emissions groups may not necessarily cause this attachment 

to be updated. 

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity 

Mobile Sources 1. Cleaning and sweeping of streets and paved surfaces X 

1. Fire fighting and similar safety equipment used to train fire fighters or other emergency 

personnel. X 

2. Small incinerators that are not subject to any standard, limitation or other requirement under 

Section 111 or 112 (excluding 112(r)) of the Federal Act and are not considered a "designated 

facility" as specified in 40 CFR 60.32e of the Federal emissions guidelines for 

Hospital/Medical/Infectious Waste Incinerators, that are operating as follows: 

i) Less than 8 million BTU/hr heat input, firing types 0, 1, 2, and/or 3 waste. 0 

ii) Less than 8 million BTU/hr heat input with no more than 10% pathological (type 4) waste 

by weight combined with types 0, 1, 2, and/or 3 waste. 0 

iii) Less than 4 million BTU/hr heat input firing type 4 waste. 

(Refer to 391-3-1-.03(10)(g)2.(ii) for descriptions of waste types) 0 

3. Open burning in compliance with Georgia Rule 391-3-1-.02 (5). X 

4. Stationary engines burning: 

i) Natural gas, LPG, gasoline, dual fuel, or diesel fuel which are used exclusively as 

emergency generators shall not exceed 500 hours per year or 200 hours per year if subject 

to Georgia Rule 391-3-1-.02(2)(mmm).7 

4 

ii) Natural gas, LPG, and/or diesel fueled generators used for emergency, peaking, and/or 

standby power generation, where the combined peaking and standby power generation do 

not exceed 200 hours per year. 

0 

iii) Natural gas, LPG, and/or diesel fuel used for other purposes, provided that the output of 

each engine does not exceed 400 horsepower and that no individual engine operates for 

more than 2,000 hours per year. 

2 

Combustion 

Equipment 

iv) Gasoline used for other purposes, provided that the output of each engine does not exceed 

100 horsepower and that no individual engine operates for more than 500 hours per year. 0 

Trade Operations 1. Brazing, soldering, and welding equipment, and cutting torches related to manufacturing and 

construction activities whose emissions of hazardous air pollutants (HAPs) fall below 1,000 

pounds per year. 

X 

Maintenance, 

Cleaning, and 

Housekeeping 

1. Blast-cleaning equipment using a suspension of abrasive in water and any exhaust system (or 

collector) serving them exclusively. 0 

 2. Portable blast-cleaning equipment. 1 

 3. Non-Perchloroethylene Dry-cleaning equipment with a capacity of 100 pounds per hour or less 

of clothes. 0 

 4. Cold cleaners having an air/vapor interface of not more than 10 square feet and that do not use a 

halogenated solvent. 9 

 5. Non-routine clean out of tanks and equipment for the purposes of worker entry or in preparation 

for maintenance or decommissioning. X 

 6. Devices used exclusively for cleaning metal parts or surfaces by burning off residual amounts of 

paint, varnish, or other foreign material, provided that such devices are equipped with 

afterburners. 

0 

 7. Cleaning operations: Alkaline phosphate cleaners and associated cleaners and burners. 0 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 3 of 8 

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity 

Laboratories 

and Testing 

1. Laboratory fume hoods and vents associated with bench-scale laboratory equipment used for physical or 

chemical analysis. 6 

 2. Research and development facilities, quality control testing facilities and/or small pilot projects, where 

combined daily emissions from all operations are not individually major or are support facilities not 

making significant contributions to the product of a collocated major manufacturing facility. 

0 

1. Sanitary waste water collection and treatment systems, except incineration equipment or equipment 

subject to any standard, limitation or other requirement under Section 111 or 112 (excluding 112(r)) of 

the Federal Act. 

9 

2. On site soil or groundwater decontamination units that are not subject to any standard, limitation or 

other requirement under Section 111 or 112 (excluding 112(r)) of the Federal Act. 0 

3. Bioremediation operations units that are not subject to any standard, limitation or other requirement 

under Section 111 or 112 (excluding 112(r)) of the Federal Act. 0 

Pollution 

Control 

4. Landfills that are not subject to any standard, limitation or other requirement under Section 111 or 112 

(excluding 112(r)) of the Federal Act. 0 

1. Concrete block and brick plants, concrete products plants, and ready mix concrete plants producing less 

than 125,000 tons per year. 0 

2. Any of the following processes or process equipment which are electrically heated or which fire natural 

gas, LPG or distillate fuel oil at a maximum total heat input rate of not more than 5 million BTU's per 

hour: 

i) Furnaces for heat treating glass or metals, the use of which do not involve molten materials or oilcoated parts. 0 

ii) Porcelain enameling furnaces or porcelain enameling drying ovens. 0 

iii) Kilns for firing ceramic ware. 0 

iv) Crucible furnaces, pot furnaces, or induction melting and holding furnaces with a capacity of 1,000 

pounds or less each, in which sweating or distilling is not conducted and in which fluxing is not 

conducted utilizing free chlorine, chloride or fluoride derivatives, or ammonium compounds. 

0 

v) Bakery ovens and confection cookers. 0 

vi) Feed mill ovens. 0 

vii) Surface coating drying ovens 0 

3. Carving, cutting, routing, turning, drilling, machining, sawing, surface grinding, sanding, planing, 

buffing, shot blasting, shot peening, or polishing; ceramics, glass, leather, metals, plastics, rubber, 

concrete, paper stock or wood, also including roll grinding and ground wood pulping stone sharpening, 

provided that: 

i) Activity is performed indoors; & 

ii) No significant fugitive particulate emissions enter the environment; & 

iii) No visible emissions enter the outdoor atmosphere. 

X 

4. Photographic process equipment by which an image is reproduced upon material sensitized to radiant 

energy (e.g., blueprint activity, photographic developing and microfiche). 0 

5. Grain, food, or mineral extrusion processes 0 

6. Equipment used exclusively for sintering of glass or metals, but not including equipment used for 

sintering metal-bearing ores, metal scale, clay, fly ash, or metal compounds. 0 

7. Equipment for the mining and screening of uncrushed native sand and gravel. 0 

8. Ozonization process or process equipment. 0 

9. Electrostatic powder coating booths with an appropriately designed and operated particulate control 

system. 0 

10. Activities involving the application of hot melt adhesives where VOC emissions are less than 5 tons per 

year and HAP emissions are less than 1,000 pounds per year. 0 

11. Equipment used exclusively for the mixing and blending water-based adhesives and coatings at ambient 

temperatures. 0 

12. Equipment used for compression, molding and injection of plastics where VOC emissions are less than 

5 tons per year and HAP emissions are less than 1,000 pounds per year. 0 

Industrial 

Operations 

13. Ultraviolet curing processes where VOC emissions are less than 5 tons per year and HAP emissions are 

less than 1,000 pounds per year. 0 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 4 of 8 

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity 

1. All petroleum liquid storage tanks storing a liquid with a true vapor pressure of equal to or less 

than 0.50 psia as stored. 2 

2. All petroleum liquid storage tanks with a capacity of less than 40,000 gallons storing a liquid 

with a true vapor pressure of equal to or less than 2.0 psia as stored that are not subject to any 

standard, limitation or other requirement under Section 111 or 112 (excluding 112(r)) of the 

Federal Act. 

2 

3. All petroleum liquid storage tanks with a capacity of less than 10,000 gallons storing a 

petroleum liquid. 28 

4. All pressurized vessels designed to operate in excess of 30 psig storing petroleum fuels that are 

not subject to any standard, limitation or other requirement under Section 111 or 112 (excluding 

112(r)) of the Federal Act. 

0 

5. Gasoline storage and handling equipment at loading facilities handling less than 20,000 gallons 

per day or at vehicle dispensing facilities that are not subject to any standard, limitation or other 

requirement under Section 111 or 112 (excluding 112(r)) of the Federal Act. 

1 

6. Portable drums, barrels, and totes provided that the volume of each container does not exceed 

550 gallons. <150 

Storage Tanks and 

Equipment 

7. All chemical storage tanks used to store a chemical with a true vapor pressure of less than or 

equal to 10 millimeters of mercury (0.19 psia). 7 

INSIGNIFICANT ACTIVITIES BASED ON EMISSION LEVELS

Description of Emission Units / Activities Quantity 

Cooling Towers 4 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 5 of 8 

ATTACHMENT B (continued) 

GENERIC EMISSION GROUPS

Emission units/activities appearing in the following table are subject only to one or more of Georgia Rules 391-3-1-.02 (2) (b), (e) &/or (n). Potential 

emissions of particulate matter, from these sources based on TSP, are less than 25 tons per year per process line or unit in each group. Any emissions unit 

subject to a NESHAP, NSPS, or any specific Air Quality Permit Condition(s) are not included in this table.

Applicable Rules 

Description of Emissions Units / Activities 

Number 

of Units 

(if appropriate) Opacity 

Rule (b) 

PM from 

Mfg Process 

Rule (e) 

Fugitive Dust 

Rule (n) 

n/a 

The following table includes groups of fuel burning equipment subject only to Georgia Rules 391-3-1-.02 (2) (b) & (d).Any emissions unit subject to a 

NESHAP, NSPS, or any specific Air Quality Permit Condition(s) are not included in this table.

Description of Fuel Burning Equipment Number of Units 

Fuel burning equipment with a rated heat input capacity of less than 10 million BTU/hr burning only natural gas 

and/or LPG.

0 

Fuel burning equipment with a rated heat input capacity of less than 5 million BTU/hr, burning only distillate fuel 

oil, natural gas and/or LPG.

0 

Any fuel burning equipment with a rated heat input capacity of 1 million BTU/hr or less. 0 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 6 of 8 

ATTACHMENT C 

LIST OF REFERENCES 

1. The Georgia Rules for Air Quality Control Chapter 391-3-1. All Rules cited herein which begin with 391-3-1 

are State Air Quality Rules. 

2. Title 40 of the Code of Federal Regulations; specifically 40 CFR Parts 50, 51, 52, 60, 61, 63, 64, 68, 70, 72, 

73, 75, 76 and 82. All rules cited with these parts are Federal Air Quality Rules. 

3. Georgia Department of Natural Resources, Environmental Protection Division, Air Protection Branch, 

Procedures for Testing and Monitoring Sources of Air Pollutants. 

4. Georgia Department of Natural Resources, Environmental Protection Division, Air Protection Branch, 

Procedures for Calculating Air Permit Fees. 

5. Compilation of Air Pollutant Emission Factors, AP-42, Fifth Edition, Volume I: Stationary Point and Area 

Sources. This information may be obtained from EPA's TTN web site at 

www.epa.gov/ttn/chief/ap42/index.html. 

6. The latest properly functioning version of EPA's TANKS emission estimation software. The software may be 

obtained from EPA's TTN web site at www.epa.gov/ttn/chief/software/tanks/index.html. 

7. The Clean Air Act (42 U.S.C. 7401 et seq). 

8. White Paper for Streamlined Development of Part 70 Permit Applications, July 10, 1995 (White Paper #1). 

9. White Paper Number 2 for Improved Implementation of the Part 70 Operating Permits Program, March 5, 

1996 (White Paper #2) 
Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 7 of 8 

ATTACHMENT D 

U.S. EPA ACID RAIN PROGRAM PERMIT APPLICATION 

FOR PHASE II NOX AVERAGING PLAN 









Title V Permit 

Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0 

Appendix Page 8 of 8 

ATTACHMENT E 

CAIR PERMIT APPLICATION FOR SO2 and NOX 

ANNUAL TRADING PROGRAMS 

.