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

i 

### 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 (R elated to Data Collection) ....................................17
5.1 General Monitoring Requirements................................................................................................ .....17
5.2 Specific Monitoring Requirements ............................................................................................... .....17
PART 6.0 RECORD KEEPING AND REPO RTING 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 Pe rmits and Am endments.............................................................................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................................................................................................................. .................52Title 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 Re quirements ........................................................................................................ .........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 Spec ific Abbreviations B. Insignificant Activities Checklist, Insignificant Activities Based on Emissi on Levels and Generic Emission Groups
C. List of References D. U.S. EPA Acid Rain Program Permit Application for Phase II NO X Averaging Plan E. CAIR Permit Application for SO 2 and NO X Annual Trading ProgramsTitle 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 possi bly be contiguous or adjacent and under common
control.

1.2 Previous and/or Other Names

This facility is commonly known as Plant Sche rer. 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 Fl ue Gas Desulfurization (FGD) scrubbers are being installed on Steam Genera ting 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 insta lled. 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 th ese 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 PERTAINI NG 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 Fe deral 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 specifica lly 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 referen ce test method(s) or pr ocedures 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/aTitle 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 requirement s contained in this permit may also apply to emission units listed above. The lists of appli cable

requirements/standards and corresponding pe rmit 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 th an 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 th e 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 c overed by 3.2.1b.) or municipal solid waste except as may be spec ifically 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 a nd the binder constitutes approximately 2.5% by weight or less of the coal-derived synthe tic 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) duri ng periods of startup or s hutdown. For the purposes of this permit, startup shall be de fined as the period lasting from the time the first oil fire is
established in the furnace until the time th at 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, th e 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 (Emissi on 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 NO X Emission Limits for the 7-Plant Plan 3.2.4 The Permittee shall not discharge, or cause the discharge, into the atmosphere NO X emissions, including emissions occurring during startup and shutdown, from the combined operations of all affected units (Emissi on Unit IDs SG01, SG02, SG03, SG04 at Plant Bowen (AFS No. 015-00011); SG01, SG02, SG 03, SG04 at Plant Branch (AFS No. 237- 00008); SG01, SG02, SG03, SG04 at Plan t 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 a nd 391-3-1-.03(8)(c)15]

3.3 Equipment Federal Rule Standards

3.3.1 The Permittee shall be subject to all appli cable requirements of 40 CFR 60 - Standards of Performance for New Stationary Sour ces, Subpart A - General Provisions. [40 CFR 60 Subpart A]

3.3.2 The Permittee shall not discha rge or cause the discharge in to the atmosphere from any steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam generating source, any gases which contain pa rticulate matter in excess of 0.10 lb/MMBtu heat input. [40 CFR 60.42(a)(1), 39 1-3-1-.02(2)(d)2(iii)]

3.3.3 The Permittee shall not discha rge or cause the discharge in to the atmosphere from any steam generating unit (Emission Unit IDs SG 01, SG02, SG03, or SG04) any gases that exhibit equal to or greater th an 20 percent opacity (6-minut e 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 discha rge or cause the discharge in to the atmosphere from any steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam generating source, any gases which contain sulf ur dioxide in excess of 1.2 lb/MMBtu heat input. [40 CFR 60.43(a)(2), 39 1-3-1-.02(2)(g)1(ii)]

3.3.5 The Permittee shall not discha rge or cause the discharge in to the atmosphere from any steam generating unit (Emission Unit IDs SG01, SG02, SG03, or SG04), or steam generating source, any gases wh ich contain nitrogen oxides in excess of 0.7 lb/MMBtu heat input. [40 CFR 60.44(a)(3), 39 1-3-1-.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 pa rticulate 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 saturate d 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, wh ere such screening operations, bucket elevators, and belt conveyors process satura ted 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 build ing may not exhibit greater than 7 percent opacity.

f. emissions from a powered building vent wh ich contain particulate matter in excess of 0.032 g/dscm (0.014 grains/dscf).

Note: Unloading of nonmetallic minerals fr om movable vehicles designed to transport nonmetallic minerals from one location to another, includi ng but not limited to: trucks, front end loaders, skip hoists, and railcars into any screeni ng operation, feed hopper, or crusher is exempt from the re quirements 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, S ubpart UUUUU, "National Emission Standards for
Hazardous Air Pollutants from Coal and Oil-Fi red Electric Utility Steam Generating Units" for operation of steam generating units (E mission 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 discha rge or cause the discharge in to the atmosphere from any startup boiler (Emission Unit IDs SB01 or SB 02) 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 discha rge or cause the discharge in to the atmosphere from any startup boiler (Emission Un it IDs SB01 or SB02) any gases that exhibit equal to or greater than 20 percent opacity (6- minute average), ex cept 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 an y start-up boiler (Emi ssion Unit IDs SB01 or SB02) that contains greater th an 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 preven t 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]

NO X 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 fr om steam generating unit with Emission Unit ID SG01 at Plant Scherer (AFS No. 207-00008) NO X 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 fr om steam generating unit with Emission Unit ID SG02 at Plant Scherer (AFS No. 207-00008) NO X 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 fr om steam generating unit with Emission Unit ID SG03 at Plant Scherer (AFS No. 207-00008) NO X 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 fr om steam generating unit with Emission Unit ID SG04 at Plant Scherer (AFS No. 207-00008) NO X 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 w ith Condition Nos. 3.4.6, 3.4.7, 3.4.8, or 3.4.9, the
Permittee shall demonstrate that NO X 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 (A FS No. 237-0008); SG01, SG02, SG03, SG04 at Plant Hammond (AFS No. 115-00003); SGM1, SG M2 at Plant McDonough (AFS No. 067- 00003); SG01, SG02, SG03, SG04 at Plant Sche rer (AFS No. 207-00008); SG01, SG02 at Plant Wansley (AFS No. 149-00001); an d SG01, SG02, SG03, SG04, SG05, SG06, SG07 at Plant Yates (AFS No. 077-00001)), do not ex ceed 0.18 lb/MMBtu he at input on a 30-day rolling averaging period. This condition sh all 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 w ith Condition Nos. 3.4.6, 3.4.7, 3.4.8, or 3.4.9, the
Permittee shall demonstrate that NO X 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 discha rge, 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 = 4.1P 0.67 ; orTitle V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 9 of 65 b. For process input weight rate above 30 tons per hour:
E = 55P 0.11 – 40

where E equals the allowable PM emission ra te 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 equippe d and operated with so rbent 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 Utili ty Steam Generating Units [as listed in this Condition] at a facility are down and off-s ite power is not ava ilable (also known as a “Black Start”).

b. Periods of startup of an EGU provided th at 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 th at 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 preventa tive maintenance of control technology equipment if such maintenance cannot re asonably 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 re quirements of Paragraph 391-3-1-.02(2)(a)7.

f. Periods when the owner/operator is requi red to conduct the Relative Accuracy Test Audit and any other necessary periodic quality assurance procedures on the Continuous Emissions Monitoring System lo cated on the bypass st ack pursuant to 40 CFR Part 75 or the Georgia De partment of Natural Resources Procedures for Testing and Monitoring Sources of Air Pollutants

.

g. Periods when the owner/operator is require d to conduct any performance tests on the bypass stack as required by stat e or federal air quality ru les, air quality operating permits, or as ordered by the Division.

h. Division approved periods of research and development of emission control technologies, provided that th e unit does not exceed other ap plicable 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)Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 10 of 65 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 demons tration that any increase in emissions resulting from the R&D project that ar e above that which is allowed by this subparagraph (sss) will not cause or significa ntly 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 subpa ragraph 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 SG 01, 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 catalyti c 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 Utili ty Steam Generating Units [as listed in this Condition] at a facility are down and off-s ite power is not ava ilable (also known as a “Black Start”).

b. Periods of startup of an EGU provided th at 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 th at 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 preventa tive maintenance of control technology equipment if such maintenance cannot re asonably 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 re quirements of Paragraph 391-3-1-.02(2)(a)7.

f. Periods when the owner/operator is requi red to conduct the Relative Accuracy Test Audit and any other necessary periodic quality assurance procedures on the Continuous Emissions Monitoring System lo cated on the bypass st ack pursuant to 40 CFR Part 75 or the Georgia De partment of Natural Resources Procedures for Testing and Monitoring Sources of Air Pollutants.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 11 of 65 g. Periods when the owner/operator is require d to conduct any performance tests on the bypass stack as required by stat e or federal air quality ru les, air quality operating permits, or as ordered by the Division.

h. Division approved periods of research and development of emission control technologies, provided that th e unit does not exceed other ap plicable 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 demons tration that any increase in emissions resulting from the R&D project that ar e above that which is allowed by this subparagraph (sss) will not cause or significa ntly 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 subpa ragraph 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 disc harge, into the atmosphere, any gases which
contain SO 2 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 generatin g unit SG04, except for pe riods indicated in Condition No. 3.4.19, the Permittee sh all not discharge, or cause the discharge, into the atmosphere, any gases which contain SO 2 emissions in excess of 5 percent (0.05) of the potential combustion concentration (95 per cent reduction) on a 30-day rolling average
basis. [391-3-1-.02(2)(uuu)2]

3.4.17 Effective January 1, 2014 for steam generatin g unit SG02, except for pe riods indicated in Condition No. 3.4.19, the Permittee sh all not discharge, or cause the discharge, into the atmosphere, any gases which contain SO 2 emissions in excess of 5 percent (0.05) of the potential combustion concentration (95 per cent reduction) on a 30-day rolling average
basis. [391-3-1-.02(2)(uuu)2]

3.4.18 Effective January 1, 2015 for steam generatin g unit SG01, except for pe riods indicated in Condition No. 3.4.19, the Permittee sh all not discharge, or cause the discharge, into the atmosphere, any gases which contain SO 2 emissions in excess of 5 percent (0.05) of the potential combustion concentration (95 per cent reduction) on a 30-day rolling average
basis. [391-3-1-.02(2)(uuu)2]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 12 of 65 3.4.19 For purposes of this permit, require ments 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-s ite power is not ava ilable (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 requiremen ts outlined in the Georgia Rules for Air Quality Control 391-3-1-.02(2)(a)7.

c. Periods of shutdown of an Electric Utili ty Steam Generating Unit provided that such periods are consistent with the requiremen ts outlined in the Georgia Rules for Air Quality Control 391-3-1-.02(2)(a)7.

d. Periods of scheduled and/or preventa tive maintenance of control technology equipment if such maintenance cannot re asonably be performed during a scheduled outage of the respective Electric Utility Steam Generating Unit.

e. Periods of malfunction of an Electric Ut ility Steam Generating Unit and/or control technology equipment provided that such peri ods 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 Syst em (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 perfor mance testing on the bypass stack as required by Stat e or Federal air quality ru les, air qual ity operating permits or at the re quest of the Division.

h. Division-approved periods of research and development of emission control technologies provided that the unit does not exceed other applicable em ission 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 resear ch 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 demons tration that any increase in emissions resulting from the R&D project that ar e above that which is allowed by this subparagraph (uuu) will not cause or signifi cantly contribute to an violation of any national ambient air quality standard or prevent compliance with any other applicable provisions.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 13 of 65 3.5 Equipment 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 14 of 65 PART 4.0 REQUIREMENTS FOR TESTING

4.1 General Testing Requirements

4.1.1 The Permittee shall cause to be conducted a pe rformance test at any specified emission unit when so directed by the Envir onmental Protection Division (“Di vision”). 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 c onducted 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 determina tion 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 se ction, to emission rates (i.e., lb/MMBtu),Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 15 of 65 j. The procedures contained in Section 2.116.2 of the above-referenced document shall be used for the determination of nitrog en 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 nitr ogen 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. SG 01, SG02, SG03 and SG04 for purposes of verifying compliance with Geor gia Rule 391-3-1-.02(2)(uuu).

Minor changes in methodology may be specif ied or approved by the Director or his designee when necessitated by process variab les, changes in facility design, or improvement or corrections that, in his opini on, 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 no tification 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 Gene rating Units (Emission Unit ID Nos. SG01, SG02, SG03 and SG04) scrubber bypass stac ks (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 th e previous test of that unit, whichever
comes first. Prior to the effective date s of Georgia Rule 391-3-1-.02(2)(uuu) for Units 1, 2, 3, and 4, the Permittee may, if resu lts from the previous tests are fifty percent or less of th e limitation in Condition 3.3.2, request that testing be deferred for a period of no greater than 8760 operati ng 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 Genera ting 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)]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 16 of 65 4.2.2 [Reserved]

4.2.3 The Permittee shall conduct a repeat perf ormance 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 Conditio n 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 pe rformance test(s) on the following emissions units at the frequency specified:

a. Initial and subsequent performance te sts 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 th e 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 SG 04, 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 th e first day of the 30 consecuti ve operating days is completed upon the first boiler operating day on or after the applicable e ffective 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 per cent reduction for Sulfur Dioxide (SO 2 ) is calculated to show compliance w ith Conditions 3.4.15, 3.4.16, 3.4.17, and 3.4.18. Compliance with applicable pe rcent reduction requirements is determined based on the average inlet and outlet SO 2 emissions rates for the 30 succ essive boiler ope rating days. If the Permittee has not obtained the minimum qu antity 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]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 17 of 65 PART 5.0 REQUIREMENTS FOR MONITORI NG (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 reco rded 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 ma nner 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 fo llowing 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 ea ch 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 concentra tion (ppm) and diluent concen trations (either Oxygen or Carbon Dioxide, percent), located in each lin er 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 concentra tion (ppm) and diluent concen trations (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).Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 18 of 65 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 emissi ons 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 SO 2 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 ach ieving 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 th e 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 writte n request by the Division, analy ze 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. E nvironmental Protection Agency document EPA600/2-80-018 (Samplers and Sampling Proced ures 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, sh all 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 Bipheny ls 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 SO 2 CEMS as required by Condition 5.2.1f. A 3-hour rolling average SO 2 emission rate in pounds per m illion BTU shall be calculated. [40 CFR 60.45(b)(2) and 40 CFR 70.6(a)(3)(i)]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 19 of 65 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 performa nce 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 opa city data.

F. Averaging Period [64.3(b)(4)] The 6-minute opacity data is used to
calculate 3-hour block averages.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 20 of 65 5.2.7 The Permittee shall comply with the performa nce 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 opa city data.

L. Averaging Period [64.3(b)(4)] The 6-minute opacity data is used to
calculate 3-hour block averages.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 21 of 65 5.2.8 The Permittee shall comply with the performa nce 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 equi pment 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.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 22 of 65 5.2.9 The Permittee shall comply with the performa nce 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 equi pment 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, mainta in the monitoring required by Conditions 5.2.6, 5.2.7, 5.2.8, and 5.2.9, including but not limited to, ma intaining necessary parts for routine repairs of the monitoring equipment. [40 CFR 64.7(b)]

5.2.11 Except for, as applicable, monitoring malfunc tions, associated repairs, and required quality
assurance or control activitie s (including, as applicable, calibration checks and required zero and span adjustments), the Permittee sh all conduct all monito ring 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 ac tivities shall not be used for purposes of CAM, including data averages a nd calculations, or fulfilling a minimum data availability requirement, if applicable. The Pe rmittee 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 sudde n, 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

Page 23 of 65 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 pollu tant-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 incl ude minimizing the period of any startup, shutdown or malfunction and taking any necessa ry 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 comput erized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the a pplicable emission limita tion 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 resu lts, review of operation and maintenance procedures and records, and in spection 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 ach ieve compliance with an emission limitation or standard for which the approved monito ring in Conditions 5.2.6, 5.2.7, 5.2.8, and 5.2.9 did not provide an indicatio n of an excursion or exceedance wh ile providing valid data, or the results of compliance or performance testi ng 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. Su ch a modification may include, but is not limited to, reestablishing indicator ranges or designated conditi ons, modifying the frequency of conducting monitoring and collecti ng 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 syst em 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 ID s 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 specif ied in Conditions 5.2.15.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 24 of 65 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 revi ew and, if necessary to assure compliance, modification by the Division and shall include th e 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 basi s, 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 operat ion of timer and valves.

c. For baghouses equipped with reverse ai r cleaning systems, ch eck the system for proper operation. This may include checking damper, bypa ss, 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 opera tion 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 fr om 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

Page 25 of 65 5.2.17 Once each day or portion of each day of opera tion, 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 a nd 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 e xhibits 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 twel ve (12) hours and re-inspect the unit when it is operated next to verify that no visible emi ssions 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 scrubbe rs FGD1 and FGD2 the Permittee shall conduct testing to determine complianc e indicators(s) and submit an updated Compliance Assurance Monitoring (CAM) Plan for the control of pa rticulate emissions fr om 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 measur ement of the indicated parameters on the following equipment. Where such performance sp ecifications exist, each system shall meet the applicable performance sp ecifications of the Divisi on’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

Page 26 of 65 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 (ACI
m ) rates required fo r SG01, SG02, SG03, and SG04 using the following equation:

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

The value of ACI
m shall be compared to the actual ACI rates for each applicable steam generating unit for each operating minute as re quired in Condition 5.2.19b. For each hour or portion of each hour of operation, a positive si gnal 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 ACI
m 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 st artup, shutdown, malfunction or emergency conditions, except for CEMS breakdowns, repair s, 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 SO 2 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 averag es are calculated using the data points required under Section 1.4(h)(2 ) of the referenced document. If the minimum data requirement of this conditio n 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 SO 2 CEMS required by Condition 5.2.1f, at least 45 days before commencing certif ication testing of th e monitoring system. The Permittee shall comply with the requiremen ts 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 downs tream of the last control device).

b. Performance and equipment specifications for the sample interface, the pollutant concentration or parametric signal analyz er, and the data collection and reduction
systems;Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 27 of 65 c. Performance evaluation procedures and accep tance 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 SO 2 , CO 2 , and O 2 CEMS required by Condition 5.2.1 sha ll be installed, certified, and operated in accordance with the applicable proc edures 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 Appe ndix 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

Page 28 of 65 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 th is Permit shall be recorded in a permanent form suitable for in spection 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) an d 40 CFR 70.6(a)(3)]

6.1.2 In addition to any other reporting requirements of this Permit, the Pe rmittee shall report to the Division in writing, within seven (7) days , any deviations from applicable requirements associated with any malfunction or breakdow n 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 pr obable cause of the deviation(s), duration of the de viation(s), and any co rrective 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 a ny 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 requir ement contained in this permit which are not otherwise reported in accordance with Cond itions 6.1.4 or 6.1.2. Such failures shall be determined through observation, data from a ny 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 e ach 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 fa ilure(s), and any co rrective actions or preventive measures taken. [391-3-1-.03(10)(d)1.(i) a nd 40 CFR 70.6(a)(3)(iii)(B)]

6.1.4 The Permittee shall submit a written report co ntaining 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 follo w required work practice procedures.

b. Total process operating time during each reporting period.Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 29 of 65 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 a nd 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, s hutdowns, or malfunctions of the affected facility. Include the natu re and cause of any malfunc tion (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 repa irs, adjustments, or replacement. When the monitoring system or device has not been inoperative, repaire d, 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) a nd 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, an d 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 measur ements, reports, maintenance and records. [391-3-1-.03(10)(d)1(i) a nd 40 CFR 70.6 (a)(3)(ii)(B)]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

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 exces s 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 purpos e of this Condition and Condition 6.1.4, any condition that is detected by monitoring or record keeping whic h 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 SG 01, 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 r ecord keeping that prov ides data in terms
of an emission limitation or standard and th at indicates that emi ssions (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 th rough September 30) total NO X emission rate which exceeds 32,335.8 tons from the a pplicable equipment specified in
Condition 3.2.6.

iii. Any 30 day rolling average SO 2 percent reduction that is calculated in accordance with the procedures of Cond ition 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 Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 31 of 65 c. Excursions: (means for the purpose of this Condition and Condition 6.1.4, any departure from an indicator range or value established for monito ring consistent with any averaging period specified for aver aging 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 sha ll be defined as any one of the eight consecutive three-hour time periods be tween 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 sha ll be defined as any one of the eight consecutive three-hour time periods be tween 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 preventativ e 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 Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 32 of 65 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 operati ng hours during that period, excluding periods described in Georgia Rule s 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 mont hly 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 SG 04, 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 distilla te 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 re cords of representative samp les of the coal and sawdust burned in the steam generating units (E mission Unit IDs SG01, SG02, SG03, and SG04) for five years after the date and year of reco rd. The records shall be available for inspection or submittal to the Division, upon requ est, 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 Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 33 of 65 6.2.3 For each shipment of fuel oil received, the Permittee shall obtain from the supplier of the fuel oil, a statement certifyi ng that the oil complies with th e specifications of fuel oil contained in ASTM D396, ASTM D975, or AS TM 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 c ontent. The procedures of ASTM D4057 shall be used to acquire the sample. Sulfur content shal l be determined using th e 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) an d 40 CFR 70.6(a)(3)(i)]

6.2.4 The Permittee shall obtain from the supplier a statement certifying th at each shipment of coal derived synthetic fuel to be received co mplies 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 Pe rmittee shall observe the unloading process to ensure that the dust suppr ession system for the coal handling system (Emission Unit ID CHS) is work ing 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 we re taken to ensure that the dust suppression system is working properly and sh all 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 a ll 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 NO X Emission Caps
6.2.7 The Permittee shall use the data obtained from the NO X CEMS to compute the monthly mass emission rate, in tons per calendar month, of NO X from the following coal-fired steam generating units on a combined basis: Em ission 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, SG 02, SG03, SG04, SG05, SG06, and SG07 at Plant Yates (AFS No. 077-00001). This emission ra te 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 Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

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 NO X 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 ID s 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 ID s SG01 and SG02 at Plant Wansley (AFS No. 149-00001); Emission Unit IDs SG01, SG 02, SG03, SG04, SG05, SG06, and SG07 at Plant Yates (AFS No. 077-00001). This emission ra te 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 Verifica tion of Georgia Rule (jjj) NO X Emission Limits 6.2.9 The Permittee shall determine compliance with the NO X emissions limitations in Condition Nos. 3.4.6 through 3.4.10 using emissions data acquired by the NO X CEMS. The 30-day rolling average shall be determined as follows: [391-3-1-.02(6)(b)1(i) an d 40 CFR 70.6(a)(3)(i)]

a. The first 30-day averaging period shall be gin on the first operat ing day of the ozone

season.

b. The 30-day average shall be the average of all valid hours of NO X emissions data for any 30 successive operating days du ring the period of the ozone season.

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

season.

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

e. For the purpose of this Pe rmit, an operating day is a 24-hour period between 12:00 midnight and the following midnight during whic h 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 re cords specified in Section 2.116.4 of the aforementioned procedures document and use thes e records to prepare a quarterly report. Reportable emissions are any calcu lated 30-day rolling average NO X 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 emi ssions 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 C ondition Nos. 3.4.10 as well as the source’s respective Alternative Emi ssion 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 Emi ssion 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 exclude d) and September 30. All reports shall be postmarked by August 29 and November 29, resp ectively, 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 not ification of the actual date of initial startup of NSPS equipment including equipment description, manuf acturer, and serial nu mber 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 SO 2 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 SO 2 emissions (%P
s ) to the atmosphere shall be computed using the following equation:

%P
s = 100 ) % 100 )( % 100 (

g f R R

− −

Where:

%P
s = Percent of potential SO 2 emissions, percent;

%R f = Percent reduction from fuel pretreatment, percent; and

%R g = Percent reduction by SO 2 control system, percent.

b. The procedures of Method 19 may be used to determine percent reduction (%R f ) of sulfur by such processes as fuel pr etreatment (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 SO 2 reduction (%R g ) of any SO 2 control system. Alternatively, a co mbination of an “as fired” fuel
monitor and emission rates measured af ter the control system, following the procedures in Method 19, may be used if th e percent reduction is calculated using the average emission rate from the SO 2 control device and the average SO 2 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 Secti on 2.125.4 of the Division’s Procedures for Testing and Monitoring Sources of Air Pollutant s. 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. Re portable emissions are any calc ulated 30-day ro lling average

SO 2 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 SO 2 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 emissi ons 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 cal culations, method of de termination, and type
of fuel combusted.

f. Identification of times when hourly aver ages have been obtained based on manual sampling methods.

g. Identification of the times when the polluta nt 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 af orementioned document that does not meet the applicable accuracy specification and th e subsequent acceptab le 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 re cords specified in Section 2.125.5 of the aforementioned procedures document and use thes e records to prepare a quarterly report. Reportable emissions are any calculated 30-day rolling average SO 2 emissions rate which
exceeds the limit established in Conditi ons 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 emissi ons 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 operati ng 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 av ailable for outlet emission rates (n
o ) and inlet emission rates (n i ), as applicable.

b. The standard deviation of hourly averages for outlet emission rates (s
o ) and inlet emission rates (s i ), as applicable.

c. The lower confidence limit for the mean outlet emission rate (E
o *) and the upper confidence limit for the mean inlet emission rate (E i *), as applicable.

d. The applicable potential combustion concentration.

e. The ratio of the upper confidence lim it for the mean outlet emission rate (E
o *) and the allowable emission rate (E std ), 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 SO 2 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 da ta unavailability. Operat ions of the control system and affected facility during periods of data unavailability are to be compared with operation of the control system and affected f acility before and following the period of data unavailability. Within the signed st atement, 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 CE MS 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 fo r 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 a nd 40 CFR70.6(a)(3)(i)

6.2.20 The Permittee shall document and maintain a r ecord of the following information related to the high pressure steam tu rbine upgrades for steam gene rating 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) w hose 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 ba seline 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 explanat ion for why such amount was excluded, and any netting calcu lations, 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 ba sis, for a period of ten years following resumption of regular operations after insta llation 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 estimati ons of projected actual emissions for PSD applicability purposes as allowed by Georgi a 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 increa se 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 shal l 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 Divi sion within 60 days after the end of each year during which records must be gene rated 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 submi ssion 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 ar e 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 prov ide 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 co mmencement 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 pr oposed to occur, any change in emissions, and any Permit term or condition that is no long er 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 belo w, without a Permit revision, provided the following requirements are met: [391-3-1-.03(10)(b)6 an d 40 CFR 70.4(b)(14)]

a. Each such change shall meet all appli cable 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 not ice shall describe each such change, including the date, any change in emissi ons, pollutants emitted, and any applicable requirement that would apply as a result of the change.

c. The change shall not qualify fo r the Permit shield in Condition 8.16.1.

d. The Permittee shall keep a record describing ch anges made at the source that result in emissions of a regulated air pollutant subj ect 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 re quired 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 Activitie s 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 th e Permit application and White Paper #1)

7.6.1 The Permittee shall maintain records of the duration and fre quency 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 w ith Georgia Rule 391-3-1-.02(9)(b)7.

7.7 Compliance Schedule/Progress Reports [391-3-1-.03(10)(d)3 an d 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 hol ds under Title IV of the 1990 CAAA, or the regulations promulga ted thereunder, are expressly prohibited. [40 CFR 70.6(a)(4)]

7.9.2 Permit revisions are not required for incr eases in emissions th at are authorized by allowances acquired pursuant to the State’ s Acid Rain Program, provided that such increases do not require a permit revisi on 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 promulga ted 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 st ringent than an appli cable 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 SO 2 Allowance Allocations and NO X Requirements for each affected unit. [40 CFR 73 (SO 2 ) and 40 CFR 76 (NO X )]

2011 2012 2013 2014 2015

SO 2 Allowances 21121 21121 21121 21121 21121 EMISSION

UNIT ID

SG01 EPA

ID

1 NO
X Limit The standard annual average NO X 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 NO X averaging plan as described below. Pursuant to 40 CFR 76.11, Georgia EPD approves five NO X 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 NO X 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 NO X emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NO X 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 c ontemporaneous annual em ission 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 Qua lity, the Alabama Depart ment of Environmental Management, the Florida Department of Envi ronmental Protection, and the Jefferson County Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NO X compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NO X 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

SO 2 Allowances 21270 21270 21270 21270 21270 EMISSION

UNIT ID

SG02 EPA

ID

2 NO
X Limit The standard annual average NO X 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 NO X averaging plan as described below. Pursuant to 40 CFR 76.11, Georgia EPD approves five NO X 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 NO X 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 NO X emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NO X 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 c ontemporaneous annual em ission 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 Qua lity, the Alabama Depart ment of Environmental Management, the Florida Department of Envi ronmental Protection, and the Jefferson County Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NO X compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NO X 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

SO 2 Allowances 21304 21304 21304 21304 21304 EMISSION

UNIT ID

SG03 EPA

ID

3 NO
X Limit The standard annual average NO X 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 NO X averaging plan as described below. Pursuant to 40 CFR 76.11, Georgia EPD approves five NO X 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 NO X 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 NO X emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NO X 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 c ontemporaneous annual em ission 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 Qua lity, the Alabama Depart ment of Environmental Management, the Florida Department of Envi ronmental Protection, and the Jefferson County Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NO X compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NO X 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

SO 2 Allowances 21280 21280 21280 21280 21280 EMISSION

UNIT ID

SG04 EPA

ID

4 NO
X Limit The standard annual average NO X 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 NO X averaging plan as described below. Pursuant to 40 CFR 76.11, Georgia EPD approves five NO X 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 NO X 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 NO X emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NO X 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 c ontemporaneous annual em ission 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 Qua lity, the Alabama Depart ment of Environmental Management, the Florida Department of Envi ronmental Protection, and the Jefferson County Department of Health (Alabama) have also approved this averaging plan.

In addition to the described NO X compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NO X compliance plan and requirements covering excess emissions.

Note: The number of allowances allocated to Ph ase II affected units by U.S. EPA may change as
a result of revisions to 40 CFR Part 73. In a ddition, the number of allo wances actually held by an affected source in a unit account may diff er from the number allocated by U.S. EPA.
Neither of the aforementioned conditions necessitates a revision to the unit SO 2 allowance allocations identified in this permit (See CFR 72.84).

7.9.8 Permit Application: The Phase II Acid Ra in Permit Application, Compliance Plan, and

NO X 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 pr ovisions 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 Pa rt 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 re gistration 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 define d in 40 CFR 68.22(a); and submit in the
RMP the worst-case release scenar io as provided in 40 CFR 68.165. ii. Complete the five-year accident histor y 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 RM P 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 follo wing 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 follo wing 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 68.175Title 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 (informa tion 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 Requirem ents (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 Pa rt 82, Subpart F, except as provided for motor vehicle air conditioners (MVACs) in Subpart B:

a. Persons opening appliances for maintenance, service, repair, or di sposal must comply with the required practic es pursuant to 40 CFR 82.156.

b. Equipment used during the maintenance, servic e, repair, or disposal of appliance must comply with the standards for recycling a nd recovery equipment pursuant to 40 CFR
82.158.

c. Persons performing maintenan ce, service, repair, or dispos al of appliances must be certified by an approved technician cert ification 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 industria l 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 (f leet) vehicles and if th is service involves an ozone-depleting substance (refrigerant) in th e 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 ve hicle in which final assembly of the vehicle has not been comple ted. 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, a nd 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 Applicat ion, 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 standa rd 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

Page 51 of 65 7.15.2 The owners and operators of the s ource shall comply with the Annual NO X Allowance
Allocations in accordance with th e 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 NO X Allowances (tpy) 17377 17377Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 52 of 65 PART 8.0 GENERAL PROVISIONS

8.1 Terms and References

8.1.1 Terms not otherwise defined in the Permit sha ll 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 a pply 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 enfor ceable 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, “Inspe ctions, 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 w ith all conditions of this op erating 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 reis suance, or modification; or for denial of a Permit renewal application. Any noncompliance with a Pe rmit condition specifically designated as enforceable only by the State constitutes a viol ation of the Georgia Air Quality Act and/or State rules only and is grounds for enforcem ent 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 reduc e the Permitted activity in order to maintain compliance with the conditions of this Permit. [391-3-1-.03(10)(d)1(i) a nd 40 CFR 70.6(a)(6)(ii)]

8.3.3 Nothing in this Permit shall alter or affect th e liability of the Permitt ee for any violation of applicable requirements prior to or at the time of Permit issuance. [391-3-1-.03(10)(d)1(i) a nd 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 accordan ce 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 expiratio n 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 th e 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 subj ect to the same procedural re quirements, 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, author ization to operate sha ll 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 ope rators shall obtain a
new Permit from the Director. The new Perm it may be processed as an administrative amendment if no other change in this Perm it is necessary, and provided that a written agreement containing a specific date for transf er 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) a nd 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, notifica tions, 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 mo nitoring 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 ce rtification 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 in formation 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, info rmation that the Division may request to determine whethe r cause exists for modifyi ng, revoking and reissuing, or terminating the Permit, or to determine co mpliance 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 cl aimed to be confidential, the Permittee may furnish such records directly to the EPA, if necessary, along with a cl aim 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

Page 55 of 65 8.10 Modifications

8.10.1 Prior to any source commencing a modifica tion 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 a pplication shall be submitted sufficiently in advance of any critical date involved to allow adequate ti me for review, discussion, or revision of plans, if necessary. Such app lication shall include, but not be limited to, information describing the precise nature of the change, modifications to any emission control system, production capaci ty of the plant before a nd 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 cons truct or modify (otherwise known as a SIP application) and shall be submitted on form s 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 l onger. In this case, the reopening shall be completed no later than eight een (18) months after prom ulgation of the applicable requirement. A reopening shall not be requi red 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 th e 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 shal l 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 ma de 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 not ice 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 notificat ion of planned changes or anticipated noncompliance, shall not stay any Permit condition. [391-3-1-.03(10)(d)1(i) a nd 40 CFR 70.6(a)(6)(iii)]

8.11.5 A Permit revision shall not be required for ch anges that are explicitly authorized by the
conditions of this Permit.

8.11.6 A Permit revision shall not be required for ch anges that are part of an approved economic incentive, marketable Permit, emission tradin g, 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 le gal 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 arisi ng from sudden and reasonably unforeseeable events beyond the control of the source, in cluding acts of God, wh ich 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 im properly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. [391-3-1-.03(10)(d)7 an d 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 affi rmative defense to an action brought for noncompliance with the technology-based emission limitations if the Permittee demonstrates, through properly signed contempo raneous 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 em ergency. This notice must contain a description of the emergency, any steps ta ken 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 an d 40 CFR 70.6(g)(4)]

8.13.4 The emergency conditions listed above ar e in addition to any emergency or upset provisions contained in any applicable requirement. [391-3-1-.03(10)(d)7 an d 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 certificati on shall include, but not be limited to, the following elements: [391-3-1-.03(10)(d)3 an d 40 CFR 70.6(c)(5)]

a. The identification of each term or condi tion of the Permit that is the basis of the certification;Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 58 of 65 b. The status of compliance with the terms and conditions of the permit for the period covered by the certificati on, including whether compliance during the period was continuous or intermittent, based on the me thod 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 co mpliance 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 ot her means used by the owner or operator for determining the compliance status w ith each term and condition during the certification period;

d. Any other information that must be include d to comply with s ection 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 othe r documents as may be required by law, the Permittee shall allow authorized represen tatives of the Divi sion to perform the following: [391-3-1-.03(10)(d)3 an d 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 facili ties, equipment (including monitoring and air pollution control equipment), practices , or operations re gulated 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 interfer e with any such authorized representative while in the process of carrying out his offici al duties. Refusal of entry or access may constitute grounds for Permit revocation a nd 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

Page 59 of 65 b. For applicable requirements that beco me 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 applicab le 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 start up, shutdown, or malfunction of any source which occur though ordinary diligence is empl oyed 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 cont rol equipment is operated in a manner consistent with good air pollution cont rol 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 pr ocess failure which may reasonably be prevented during startup, shutdown or malfunc tion 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 Geor gia 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 Standard s 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 c onstitute a violation of an applicable emission standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance w ith an opacity standard or with a standard which is based on the concentration of the po llutants in the gases discharged into the atmosphere. [391-3-1-.03(2)(c)]Title V Permit Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 60 of 65 8.16 Permit Shield

8.16.1 Compliance with the terms of this Permit sha ll be deemed compliance with all applicable requirements as of the date of Permit issuan ce 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 start up, shutdown, and malfunction, the Permittee shall maintain and operate the source, including asso ciated air pollution control equipment, in a manner consistent with good air pollution co ntrol practice for minimizing emissions. Determination of whether acceptable operating a nd 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 othe r characteristics of emissions, review of operating and maintenan ce 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, th e 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 lif e or use of property in such area of the
State as is affected there by. 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 a ny air contaminant source the opacity of which is equal to or greater th an 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, perm it, or allow the emission of fly ash and/or other particulate matter from a ny fuel-burning equipment with ra ted 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 Scherer Steam-Electric Generating Plant Permit No.: 4911-207-0008-V-03-0

Page 61 of 65 8.19.2 The Permittee shall not cause, let, suffer, perm it, or allow the emission of fly ash and/or other particulate matter from a ny fuel-burning equipment with ra ted 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, pe rmit, or allow the emission from any fuelburning equipment constructed or extensiv ely 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 provision s 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 allowabl e 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 allowa ble rates of emission from new equipment:

E = 4.1P 0.67 ; for process input weight rate up to and including 30 tons per hour.
E = 55P 0.11 - 40; for process input weightrate above 30 tons per hour.

b. The following equation shall be used to calc ulate the allowable ra tes of emission from existing equipment:

E = 4.1P 0.67

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 provision s of this Permit, the Permittee shall take all reasonable precautions to prevent dust from a ny operation, process, handling, transportation or storage facility from becoming airborne. Reasonable precautions th at 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, constructi on operations, the grad ing of roads or the clearing of land;

b. Application of asphalt, water, or suita ble chemicals on dirt roads, materials, stockpiles, and other surfaces that can give rise to airborne dusts;

c. Installation and use of hoods, fans, and fabr ic filters to enclose and vent the handling of dusty materials. Adequate cont ainment 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 mate rial from paved streets onto which earth or other material has been deposited.

8.22.2 The opacity from any fugitive dust sour ce 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 th e volatile organic com pounds 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 de vice to drain cleaned parts before removal from the unit,

c. If the solvent volatility is 0.60 psi or grea ter measured at 100 oF, or if the solvent is heated above 120 oF, then one of the follo wing 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), orTitle 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 chil ler 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 t ype 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 ev aporation into the atmosphere.

8.24 Incinerators

8.24.1 Except as specified in the section dealing w ith conical burners, no pe rson 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 a nd/or particulate matte r 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 incinera tor, 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 800 o F; and

c. It has a secondary burner to control sm oke and/or odors and maintain a temperature
of at least 1500 o 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 requi rements of Rule 391-3- 1-.02(2)(vv) “Volatile Organic Liquid Handli ng and Storage” is equipped with submerged fill pipes. For the purposes of this conditi on and the permit, a submerged fill pipe is defined as any fill pipe with a discharge openi ng 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 app licable rule or regula tion or requirement of this permit, for the purpose of submission of compliance cer tifications 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 Emissi on Limitation or Standard to which it pertains, shall preclude the use, includi ng the exclusive use, of any cr edible evidence or information,
relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or complian ce 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 appli cable provisions of Ne w Source Performance Standards (NSPS) Federal Rule 40 CFR Part 60 Subpart A-"General Provisions" and Subpart IIII-“Standards for Stationary Comp ression Ignition Internal Combustion Engines,”
for diesel-fired internal combustion e ngine(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), 39 1-3-1-.02(8)(b)77 ]

a. Equip all emergency generator engi nes with non-resettable hour meters

b. Purchase only diesel fuel with a maximu m 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 Spec ific Abbreviations B. Insignificant Activities Checklist, Insignificant Activities Based on Emissi on Levels and Generic Emission Groups
C. List of References D. U.S. EPA Acid Rain Program Permit Application for Phase II NO X Averaging Plan E. CAIR Permit Application for SO 2 and NO X Annual Trading ProgramsTitle 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 PM 10 (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 SO 2 (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

H 2 O (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

NO

x (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 BiphenylTitle 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 insignific ant 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 insignifica nt 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 us ed to train fire fighters or other emergency personnel. X

2. Small incinerators th at are not subject to any standard, limitation or other requirement under Section 111 or 112 (excluding 112(r)) of the Fede ral 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 Incinera tors, 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 ge nerators used for emerge ncy, 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 haza rdous air pollutants (HAPs) fall below 1,000 pounds per year. X

Maintenance, Cleaning, and Housekeeping 1. Blast-cleaning e quipment 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 equipmen t 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 exclus ively for cleaning metal parts or surfa ces by burning off residual amounts of paint, varnish, or other foreign material, pr ovided that such devices are equipped with
afterburners. 0

7. Cleaning operations: Alkaline phosphate cl eaners and associated cleaners and burners. 0Title 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 benc h-scale laboratory equipment used for physical or chemical analysis. 6

2. Research and development facilities, quality contro l testing facilities and/or small pilot projects, where combined daily emissions from all operations are not indi vidually 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 requi rement under Section 111 or 112 (excluding 112(r)) of
the Federal Act. 9

2. On site soil or groundwater deco ntamination units that are not subj ect to any standard, limitation or other requirement under Section 111 or 112 (excluding 112(r)) of the Federal Act. 0

3. Bioremediation operations units th at 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 ar e 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 sweati ng 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; cer amics, 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 imag e 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 exclusiv ely for sintering of glass or metals, but not including equipment used for sintering metal-bearing ores, metal scal e, 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 ap propriately designed and ope rated particulate control
system. 0

10. Activities involving the applicati on 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 exclusiv ely 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. 0Title 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 capa city 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 ex cess of 30 psig storing petroleum fuels that are not subject to any standard, limit ation or other requirement under Section 111 or 112 (excluding 112(r)) of the Federal Act. 0

5. Gasoline storage and handling equipment at lo ading 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 (e xcluding 112(r)) of the Federal Act. 1

6. Portable drums, barrels, and totes provided th at 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 4Title 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 fo llowing table are subject only to one or mo re of Georgia Rule s 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 ea ch group. Any emissions unit subject to a NESHAP, NSPS, or any specific Air Qualit y 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 s ubject only to Georgia Rules 391-3-1-.02 (2) (b) & (d).Any emis sions unit subject to a NESHAP, NSPS, or any specific Air Quality Perm it 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, bur ning 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. 0Title 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; sp ecifically 40 CFR Parts 50, 51, 52, 60, 61, 63, 64, 68, 70, 72, 73, 75, 76 and 82. All rules cited with thes e parts are Federal Air Quality Rules.

3. Georgia Department of Natural Resources, Environm ental Protection Division, Air Protection Branch, Procedures for Testing and Monitoring Sources of Air Pollutants.

4. Georgia Department of Natural Resources, Environm ental Protection Division, Air Protection Branch, Procedures for Calculating Air Permit Fees

.

5. Compilation of Air Pollutant Emissi on Factors, AP-42, Fifth Edition, Volu me I: Stationary Point and Area Sources. This information may be obt ained 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 NO X AVERAGING PLANTitle 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 SO 2 and NO X ANNUAL TRADING PROGRAMS

.