Soilworks products are the industry’s top standard due to our insistence on creating high performance soil stabilization and dust control products that stand up to rigorous testing – both in the lab and in the field. Our commitment to quality and performance has led to our involvement and testing in hundreds of real-world situations. The following library of reports, presentations, specifications, approvals and other similar documents provide you, our customer, the transparency and dependable assurance that is expected from Soilworks.
Louisville Metro Air Pollution Control District 850 Barret Avenue
Louisville, Kentucky 40204-1745
Title V Operating Permit
Permit No.: 175-00-TV (R2) Plant ID: 126
Permission is hereby given by the Louisville Metro Air Pollution Control District to operate the process(es) and equipment described herein which are located at:
Louisville Gas & Electric Company Cane Run Generating Station
5252 Cane Run Road Louisville, KY 40232
The applicable procedures of District Regulation 2.16 regarding review by the U.S. EPA and public participation have been followed in the issuance of this permit. Based on review of the application on file with the District, permission is given to operate under the conditions stipulated herein. If a renewal permit is not issued prior to the expiration date, the owner or operator may continue to operate in accordance with the terms and conditions of this permit beyond the expiration date, provided that a complete renewal application is submitted to the District no earlier than eighteen (18) months and no later than one-hundred eighty (180) days prior to the expiration date.
Application No.: |
36402 |
Application Received: 4/30/2007 |
|
56083; 62295; 62496 |
5/30/2013; 2/7/2014; 2/14/2014 |
|
64558; 65291; 66701 |
4/29/2014; 5/30/2014; 8/27/2014 |
Permit Writer: |
66718
Yiqiu Lin |
8/27/2014 |
Administratively Complete: |
6/30/2007 |
|
Date of Public Notice: 08/30/2014 {Manager1}
Air Pollution Control Officer
Date of proposed permit: 08/30/2014 {date1}
TABLE OF CONTENTS
Title V Permit Revisions/Changes…………………………………………………………………………………….. 6
List of Permit Renewal/Revision Applications……………………………………………………………………. 6
Abbreviations and Acronyms……………………………………………………………………………………………. 7
Preamble………………………………………………………………………………………………………………………… 8
General Conditions………………………………………………………………………………………………………….. 9
Emission Unit U4: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 4……. 17
U4 Applicable Regulations:…………………………………………………………………………………. 17
U4 Equipment:…………………………………………………………………………………………………… 18
U4 Control Devices:……………………………………………………………………………………………. 18
U4 Specific Conditions……………………………………………………………………………………….. 20
U4 Comments…………………………………………………………………………………………………….. 36
Emission Unit U5: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 5……. 39
U5 Applicable Regulations:…………………………………………………………………………………. 39
U5 Equipment:…………………………………………………………………………………………………… 40
U5 Control Devices:……………………………………………………………………………………………. 41
U5 Specific Conditions……………………………………………………………………………………….. 42
U5 Comments…………………………………………………………………………………………………….. 58
Emission Unit U6: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 6……. 60
U6 Applicable Regulations:…………………………………………………………………………………. 60
U6 Equipment:…………………………………………………………………………………………………… 61
U6 Control Devices:……………………………………………………………………………………………. 61
U6 Specific Conditions……………………………………………………………………………………….. 63
U6 Comments…………………………………………………………………………………………………….. 79
Emission Unit U7: Sludge processing plant………………………………………………………………………. 81
U7 Applicable Regulations:…………………………………………………………………………………. 81
U7 Equipment:…………………………………………………………………………………………………… 81
U7 Control Devices:……………………………………………………………………………………………. 82
U7 Specific Conditions……………………………………………………………………………………….. 84
U7 Comments…………………………………………………………………………………………………….. 90
Emission Unit U8: Unit 6 SDRS soda ash storage silo……………………………………………………….. 92
U8 Applicable Regulations:…………………………………………………………………………………. 92
U8 Equipment:…………………………………………………………………………………………………… 92
U8 Control Devices…………………………………………………………………………………………….. 92
U8 Specific Conditions……………………………………………………………………………………….. 93
U8 Comments…………………………………………………………………………………………………….. 96
Emission Unit U10: Coal handling facilities……………………………………………………………………… 97
U10 Applicable Regulations:……………………………………………………………………………….. 97
U10 Equipment:…………………………………………………………………………………………………. 97
U10 Control Devices…………………………………………………………………………………………… 98
U10 Specific Conditions……………………………………………………………………………………… 99
U10 Comments…………………………………………………………………………………………………. 103
Emission Unit U11: Gas turbine GT11…………………………………………………………………………… 104
U11 Applicable Regulations:……………………………………………………………………………… 104
U11 Equipment:……………………………………………………………………………………………….. 104
U11 Control Devices…………………………………………………………………………………………. 104
U11 Specific Conditions……………………………………………………………………………………. 105
U11 Comments…………………………………………………………………………………………………. 110
Emission Unit U14: Porta batch units…………………………………………………………………………….. 111
U14 Applicable Regulations:……………………………………………………………………………… 111
U14 Equipment:……………………………………………………………………………………………….. 111
U14 Control Devices…………………………………………………………………………………………. 111
U14 Specific Conditions……………………………………………………………………………………. 112
U14 Comments…………………………………………………………………………………………………. 114
Emission Unit U15: Natural gas-fired combined cycle (NGCC) unit – EGU 7……………………. 115
U15 Applicable Regulations:……………………………………………………………………………… 115
U15 Equipment:……………………………………………………………………………………………….. 116
U15 Control Devices:………………………………………………………………………………………… 117
U15 Specific Conditions……………………………………………………………………………………. 118
U15 Comments…………………………………………………………………………………………………. 136
Emission Unit U16: Natural gas-fired auxiliary boiler……………………………………………………… 138
U16 Applicable Regulations:……………………………………………………………………………… 138
U16 Equipment:……………………………………………………………………………………………….. 138
U16 Control Devices:………………………………………………………………………………………… 139
U16 Specific Conditions……………………………………………………………………………………. 140
U16 Comments…………………………………………………………………………………………………. 143
Emission Unit U18: Emergency generator………………………………………………………………………. 144
U18 Applicable Regulations:……………………………………………………………………………… 144
U18 Equipment:……………………………………………………………………………………………….. 144
U18 Control Devices:………………………………………………………………………………………… 145
U18 Specific Conditions……………………………………………………………………………………. 146
U18 Comments…………………………………………………………………………………………………. 151
Emission Unit U19: Haul Roads……………………………………………………………………………………. 152
U19 Applicable Regulations:……………………………………………………………………………… 152
U15 Equipment:……………………………………………………………………………………………….. 152
U19 Control Devices…………………………………………………………………………………………. 152
U19 Specific Conditions……………………………………………………………………………………. 153
U19 Comments…………………………………………………………………………………………………. 154
Emission Unit U20: Landfill…………………………………………………………………………………………. 155
U20 Applicable Regulations:……………………………………………………………………………… 155
U20 Equipment:………………………………………………………………………………………………… 155
U20 Control Devices…………………………………………………………………………………………. 155
U20 Specific Conditions……………………………………………………………………………………. 156
U20 Comments…………………………………………………………………………………………………. 158
Permit Shield………………………………………………………………………………………………………………. 159
Off-Permit Documents…………………………………………………………………………………………………. 159
Alternative Operating Scenario……………………………………………………………………………………… 159
Insignificant Activities…………………………………………………………………………………………………. 159
Emission Unit IA1: Gasoline storage tank………………………………………………………………………. 161
IA1 Applicable Regulations:………………………………………………………………………………. 161
IA1 Equipment:………………………………………………………………………………………………… 161
IA1 Control Devices:…………………………………………………………………………………………. 161
IA1 Specific Conditions…………………………………………………………………………………….. 162
IA1 Comments…………………………………………………………………………………………………. 164
Emission Unit IA2: Parts washers with secondary reservoirs…………………………………………….. 165
IA2 Applicable Regulations:………………………………………………………………………………. 165
IA2 Equipment:………………………………………………………………………………………………… 165
IA2 Control Devices:…………………………………………………………………………………………. 165
IA2 Specific Conditions…………………………………………………………………………………….. 166
IA2 Comments…………………………………………………………………………………………………. 168
Emission Unit IA-EG: Emergency generators………………………………………………………………… 169
IA-EG Applicable Regulations:………………………………………………………………………….. 169
IA-EG Equipment:……………………………………………………………………………………………. 169
IA-EG Control Devices:…………………………………………………………………………………….. 169
IA-EG Specific Conditions………………………………………………………………………………… 170
IA-EG Comment………………………………………………………………………………………………. 181
Attachment A – Protocol Checklist for a Performance Test……………………………………………….. 182
Attachment B – NOx RACT Plan – Amendment 2……………………………………………………………. 184
Part 1 of NOx RACT Plan………………………………………………………………………………….. 184
Part 2 of NOx RACT Plan………………………………………………………………………………….. 185
Appendix A to NOx RACT Plan…………………………………………………………………………. 188
Attachment C – Plant-wide Odor, Fugitive Dust, and Maintenance Emissions Control Plan Cane Run Generating Station……………………………………………………………………………………………………….. 198
Executive Summary…………………………………………………………………………………………… 198
Introduction……………………………………………………………………………………………………… 198
Section 1 – Site Description……………………………………………………………………………….. 198
Section 2 – Description of Potential Sources of Dust or Odor at Cane Run Generating Station……………………………………………………………………………………………………………………….. 199
Section 3 – Control Measures to Minimize Emissions……………………………………………. 202
Section 4 – Primary Contact List…………………………………………………………………………. 209
Attachment D – 40 CFR 75, Subpart G…………………………………………………………………………… 211
Specific Conditions…………………………………………………………………………………………… 211
Attachment E – Control Device Efficiencies and Determination Methods…………………………… 235
PHASE II ACID RAIN PERMIT………………………………………………………………………………….. 237
Acid Rain Permit Revisions/Changes…………………………………………………………………… 238
Acid Rain Permit Conditions……………………………………………………………………………… 239
Comments, Notes, and Justifications:………………………………………………………………….. 243
Permit Application:…………………………………………………………………………………………… 243
NOx Compliance Plan:………………………………………………………………………………………. 243
Title V Permit Revisions/Changes
Revision No. |
Issue Date |
Public Notice Date |
Type |
Attachment No./Page No. |
Description |
Initial |
10/1/2002 |
12/17/2000 |
Initial |
Entire Permit |
Initial Permit Issuance |
R1 |
10/1/2002 |
12/17/2000 |
Administrative |
Preamble, |
Updated preamble and |
|
|
|
|
Insignificant |
insignificant activities. |
|
|
|
|
Activities, E2, E4, |
Removed Method 22 from |
|
|
|
|
E6 |
emission points E2, E4, and |
|
|
|
|
|
E6 |
R2 |
xx/xx/2014 |
08/30/2014 |
Renewal and |
Entire Permit |
Permit renewal; R.O. change |
|
|
|
Revision |
|
and addition; Acid Rain |
|
|
|
|
|
permit revision; Incorporate |
|
|
|
|
|
construction permit 244-02, |
|
|
|
|
|
608-07, 609-07, 643-07, 119- |
|
|
|
|
|
07, 30501-11, 31791-11, |
|
|
|
|
|
34410-12 |
List of Permit Renewal/Revision Applications
Application Received Date |
Application Number |
Description |
4/30/2007 |
36402 |
TV Permit Renewal Application |
5/30/2013 |
56083 |
Incorporate two parts washers into TV permit |
2/7/2014 |
62295 |
Incorporate NGCC and associate units into TV permit |
2/14/2014 |
62496 |
Incorporate NGCC and associate units into TV permit |
4/29/2014 |
64558 |
CAIR permit application |
5/30/2014 |
65291 |
CAIR permit application revision |
Abbreviations and Acronyms
AP-42 – AP-42, Compilation of Air Pollutant Emission Factors, published by USEPA
APCD – Louisville Metro Air Pollution Control District BAC – Background Ambient Concentration
Btu – British thermal unit
CEMS – Continuous Emission Monitoring System CFR – Code of Federal Regulations
CO – Carbon monoxide
District – Louisville Metro Air Pollution Control District EA – Environmental Acceptability
ESP – Electrostatic Precipitator FGD – Flue-gas Desulfurization gal – U.S. fluid gallons
GHG – Greenhouse Gas
HAP – Hazardous Air Pollutant HCl – Hydrogen chloride
Hg – Mercury
hr – hour
in. – inches
lbs – pounds
l – liter
LMAPCD – Louisville Metro Air Pollution Control District mmHg – millimeters of mercury column height
MM – million
NAICS – North American Industry Classification System NOx – Nitrogen oxides
PM – Particulate Matter
PM10 – Particulate Matter less than 10 microns PM2.5 – Particulate Matter less than 2.5 microns ppm – parts per million
PSD – Prevention of Significant Deterioration psia – pounds per square inch absolute
QA – Quality Assurance
RICE – Reciprocating Internal Combustion Engines SIC – Standard Industrial Classification
SIP – State Implementation Plan SO2 – Sulfur dioxide
STAR – Strategic Toxic Air Reduction TAC – Toxic Air Contaminant
UTM – Universal Transverse Mercator VOC – Volatile Organic Compound
w.c. – water column
year – any period of twelve consecutive months, unless “calendar year” is specified yr – year, or any 12 consecutive-month period, as determined by context
Preamble
Title V of the Clean Air Act Amendments of 1990 (the Act) required EPA to create an operating permit program for implementation by state or local air permitting authorities. The purposes of this program are: (1) to require an affected company to assume full responsibility for demonstrating compliance with applicable regulations; (2) to capture all of the regulatory information pertaining to an affected company in a single document; and (3) to make permits more consistent with each other.
A company is subject to the Title V program if it meets any of several criteria related to the nature or amount of its emissions. The Title V operating permit specifies what the affected company is, how it may operate, what its applicable regulations are, how it will demonstrate compliance, and what is required if compliance is not achieved. In Jefferson County, Kentucky, the Louisville Metro Air Pollution Control District (LMAPCD or APCD) is responsible for issuing Title V permits to affected companies and enforcing local regulations and delegated federal and state regulations. EPA may enforce federal regulations but not “District Only Enforceable Regulations.”
Title V offers the public an opportunity to review and comment on a company’s draft permit. It is intended to help the public understand the company’s compliance responsibility under the Clean Air Act. Additionally, the Title V process provides a mechanism to incorporate new applicable requirements. Such requirements are available to the public for review and comment before they are adopted.
Title V Permit General Conditions define requirements that are generally applicable to all Title V companies under the jurisdiction of LMAPCD. This avoids repeating these requirements in every section of the company’s Title V permit. Company-specific conditions augment the General Conditions as necessary; these appear in the sections of the permit addressing individual emission units or emission points.
The General Conditions include references to regulatory requirements that may not currently apply to the company, but which provide guidance for potential changes at the company or in the regulations during the life of the permit. Such requirements may become applicable if the company makes certain modifications or a new applicable requirement is adopted.
When the applicability of a section or subpart of a regulation is unclear, a clarifying citation will be made in the company’s Title V permit at the emission unit/point level. Comments may also be added at the emission unit/point level to give further clarification or explanation.
The owner or operator’s Title V permit may include a current table of “insignificant activities.”
Insignificant activities are defined in District Regulation 2.16 section 1.23, as of the date the permit was proposed for review by U.S. EPA, Region 4.
Insignificant activities identified in District Regulation 1.02, section 1.38, and Appendix A may be subject to size or production rate disclosure requirements pursuant to Regulation 2.16 section 3.5.4.1.4.
Insignificant activities identified in District Regulation 1.02, section 1.38, and Appendix A shall comply with generally applicable requirements as required by Regulation 2.16 section 4.1.9.4.
General Conditions
US EPA – Region IV Air Pollution Control District
Air Enforcement Branch Room 205
Atlanta Federal Center 850 Barret Ave
61 Forsyth Street Louisville, KY 40204-1745
Atlanta, GA 30303-8960
This certification must be postmarked by 15 April of the year following the year for which the certification is being submitted, or other such due date as required by another applicable regulation.
upon discovery of the occurrence, promptly submit the supplementary facts or corrected information in accordance with Regulation 2.16, section 3.4.
permitted activity in order to maintain compliance with the conditions of this permit.
If information is submitted to the District under a claim of confidentiality, the source shall submit a copy of the confidential information directly to EPA at the address shown in General Condition 35.b. (Regulation 2.07, section 10.2)
unless more frequent reporting is required by an applicable requirement. The reporting period shall be 1 January through 30 June and 1 July through 31 December of each calendar year. All reports shall be sent to the District at the address shown in paragraph 2 of these General Conditions and must be postmarked by the 60th day following the end of each reporting period, unless specified elsewhere in this permit. If surrogate operating parameters are monitored and recorded in lieu of emission monitoring, then an exceedance of multiple parameters may be deemed a single violation by the District for enforcement purposes. All reports shall include the company name, plant ID number, and the beginning and ending date of the reporting period. The compliance reports shall clearly identify any deviation from a permit requirement or a declaration that there were no such deviations. All semi-annual compliance reports shall include the statement “Based on information and belief formed after reasonable inquiry, I certify that the statements and information in this document are true, accurate, and complete” and the signature and title of a responsible official of the company.
The semi-annual compliance reports are due on or before the following dates of each calendar year:
Reporting Period Report Due Date
January 1 – June 30 August 29
July 1 – December 31 March 1 of the following year
If a change in the responsible official (RO) occurs during the term of this permit, or if an RO is added, the owner or operator shall provide written notification (Form AP-100A) to the District within 30 calendar days of such change or addition.
sections 4.1.8.2 and 5.3. This permit may only be renewed in accordance with section 5.3.
Air Pollution Control District Room #205
850 Barret Ave
Louisville, KY 40204-1745
US EPA – Region IV APTMD – 12th floor Atlanta Federal Center 61 Forsyth Street
Atlanta, GA 30303-3104
Regulation |
Title |
1.01 |
General Application of Regulations and Standards |
1.02 |
Definitions |
1.03 |
Abbreviations and Acronyms |
1.04 |
Performance Tests |
1.05 |
Compliance With Emissions Standards And Maintenance Requirements |
1.06 |
Source Self-Monitoring, Emission Inventory Development and Reporting |
1.07 |
Excess Emissions During Startups, Shutdowns, and Upset Conditions |
1.08 |
Administrative Procedures |
1.09 |
Prohibition of Air Pollution |
1.10 |
Circumvention |
1.11 |
Control of Open Burning |
1.14 |
Control of Fugitive Particulate Emissions |
Regulation |
Title |
2.01 |
General Application (Permit Requirements) |
2.02 |
Air Pollution Regulation Requirements and Exemptions |
2.03 |
Authorization to Construct or Operate; Demolition/Renovation Notices and Permit Requirements |
2.07 |
Public Notification for Title V, PSD, and Other Offset Permits; SIP Revisions; and Use of Emission Reduction Credits |
2.09 |
Causes for Permit Modification, Revocation, or Suspension |
2.10 |
Stack Height Considerations |
2.11 |
Air Quality Model Usage |
2.16 |
Title V Operating Permits |
4.01 |
General Provisions for Emergency Episodes |
4.02 |
Episode Criteria |
4.03 |
General Abatement Requirements |
4.07 |
Episode Reporting Requirements |
5.02 |
Adoption and Incorporation by Reference of National Emission Standards for Hazardous Air Pollutants |
6.01 |
General Provisions (Existing Affected Facilities) |
6.02 |
Emission Monitoring for Existing Sources |
7.01 |
General Provisions (New Affected Facilities) |
7.02 |
Adoption and Incorporation by Reference of Federal New Source Performance Standards |
District Only Enforceable Regulations:
Regulation |
Title |
1.12 |
Control of Nuisances |
1.13 |
Control of Objectionable Odors |
2.08 |
Emission Fee, Permit Fees and Permit Renewal Procedures |
5.00 |
Definitions |
5.01 |
General Provisions |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
5.23 |
Categories of Toxic Air Contaminants |
comply with all requirements of 40 CFR 82, Subparts A, B, and F. Those requirements include the following restrictions:
Emission Unit U4: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 4
U4 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.02 |
Emission Monitoring for Existing Sources |
1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18 |
6.07 |
Standards of Performance for Existing Indirect Heat Exchangers |
1, 2, 3, 4 |
6.09 |
Standards of Performance for Existing Process Operations |
1, 2, 3, 5 |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound- and Nitrogen Oxides-Emitting Facilities |
1, 2, 3, 4, 5 |
6.47 |
Federal Acid Rain Program for Existing Sources Incorporated by Reference |
1, 2, 3, 4, 5 |
40 CFR 64 |
Compliance Assurance Monitoring for Major Stationary Sources |
64.1 through 64.10 |
40 CFR 72 |
Permits Regulation |
Subparts A, B, C, D, E, F, G, H, I |
40 CFR 73 |
Sulfur Dioxide Allowance System |
Subparts A, B, C, D, E, F, G |
40 CFR 75 |
Continuous Emission Monitoring |
Subparts A, B, C, D, E, F, G |
40 CFR 76 |
Acid Rain Nitrogen Oxides Emission Reduction Program |
76.1, 76.2, 76.3, 76.4, 76.5, 76.7, 76.8, 76.9, 76.11, 76.13, 76.14, 76.15, Appendix A, Appendix B |
40 CFR 77 |
Excess Emissions |
77.1, 77.2, 77.3, 77.4, 77.5, 77.6 |
40 CFR 78 |
Appeals Procedures for Acid Rain Program |
78.1, 78.2, 78.3, 78.4, 78.5, 78.6, 78.8, 78.9, 78.10, 78.11, 78.13, 78.14, 78.15, 78.16, 78.17, 78.18, 78.19, 78.20 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U4 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E1 |
One (1) dry bottom wall-fired boiler with low NOx burner, make Combustion Engineering, model Type RR, nominal rating 1,639 MMBtu/hr, using pulverized coal as the primary fuel and natural gas as the secondary fuel. |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 6.02, 6.07, 6.42, 6.47, 40 CFR 64, 40 CFR 72-73 40 CFR 75-78 |
C1, C2 |
S4 |
E2 |
Four (4) coal silos, make American Air Filter, model Type D, controlled by centrifugal dust collector and equipped with four (4) coal mills, make CE (Raymond), model 683 Type “RS” Bowl Mill. |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 6.09 |
C7 |
S1 |
Note: The owner or operator shall shut down this unit (U4) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U4 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C1 |
One (1) custom-built electrostatic precipitator (ESP), make Research Cottrell |
PM emission data from PM CEMS (if PM CEMS is not used to demonstrate compliance) |
S4 |
ID |
Description |
Performance Indicator |
Stack ID |
C2 |
One (1) Flue Gas Desulfurization (FGD) unit for SO2 control using limestone scrubbing liquor, make American Air Filter/Burns & McDonnel |
N/A (See Comment 9) |
|
C7 |
One (1) centrifugal dust collector, make American Air Filter |
N/A (See Comment 4) |
S1 |
U4 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
Compliance Options |
PM |
Opacity |
Control Device Performance indication |
Option 1 |
Certified PM CEMS |
Weekly VE/Method 9, or Certified COMS |
N/A (See Comment 9) |
Option 2 |
Annual testing |
Weekly VE/Method 9, or Certified COMS |
PM CEMS |
5.00 and 5.21) (See Comment 5)
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Biphenyl |
92-52-4 |
0.232 |
206 |
De Minimis |
Naphthalene |
91-20-3 |
0.016 |
13.9 |
De Minimis |
Acetaldehyde |
75-07-0 |
0.243 |
216 |
De Minimis |
Acetophenone |
98-86-2 |
189 |
168,000 |
De Minimis |
Acrolein (Propenal) |
107-02-8 |
|
27.3 |
Controlled PTE |
Benzene |
71-43-2 |
0.24 |
216 |
De Minimis |
Benzyl Chloride |
100-44-7 |
0.011 |
9.6 |
De Minimis |
Bis(2-ethylhexyl)phthalate (DEHP) (DOP) |
117-81-7 |
0.23 |
202 |
De Minimis |
Bromoform |
75-25-2 |
0.49 |
437 |
De Minimis |
Carbon disulfide |
75-15-0 |
378 |
336,000 |
De Minimis |
2-Chloroacetophenone |
532-27-4 |
0.016 |
14.4 |
De Minimis |
Chlorobenzene |
108-90-7 |
540 |
480,000 |
De Minimis |
Chloroform |
67-66-3 |
0.023 |
20.6 |
De Minimis |
Cumene |
98-82-8 |
0.054 |
48 |
De Minimis |
Dimethyl sulfate |
77-78-1 |
|
32.5 |
Controlled PTE |
2,4-Dinitrotoluene |
121-14-2 |
0.0059 |
5.28 |
De Minimis |
Ethyl benzene |
100-41-4 |
0.22 |
192 |
De Minimis |
Ethyl chloride |
75-00-3 |
54 |
48,000 |
De Minimis |
Ethylene dichloride |
107-06-2 |
|
27.1 |
Controlled PTE |
Ethylene dibromide |
106-93-4 |
|
37.3 |
Controlled PTE |
Formaldehyde |
50-00-0 |
|
37.3 |
Controlled PTE |
Hexane |
110-54-3 |
378 |
336,000 |
De Minimis |
Isophorone |
78-59-1 |
2.00 |
1,776 |
De Minimis |
Methyl bromide |
74-83-9 |
2.7 |
2,400 |
De Minimis |
Methyl chloride |
74-87-3 |
48.6 |
43,200 |
De Minimis |
Methyl hydrazine |
60-34-4 |
|
115 |
Controlled PTE |
Methyl methacrylate |
80-62-6 |
378 |
336,000 |
De Minimis |
Methyl-tert-butylether |
1634-04-4 |
2.079 |
1,848 |
De Minimis |
Methylene chloride |
75-09-2 |
54 |
48,000 |
De Minimis |
Phenol |
108-95-2 |
108 |
96,000 |
De Minimis |
Propionaldehyde |
123-38-6 |
4.32 |
3,840 |
De Minimis |
Styrene |
100-42-5 |
0.918 |
816 |
De Minimis |
Tetrachloroethylene (Perc) |
127-18-4 |
2.079 |
1,848 |
De Minimis |
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Toluene |
108-88-3 |
2700 |
2,400,000 |
De Minimis |
Xylene |
1330-20-7 |
54 |
48,000 |
De Minimis |
Vinyl Acetate |
108-05-4 |
171.72 |
152,640 |
De Minimis |
Hydrochloric acid |
7647-01-0 |
|
14,493 |
Controlled PTE |
Hydrogen fluoride |
7664-39-3 |
|
6,908 |
Controlled PTE |
Antimony compounds |
7440-36-0 |
0.756 |
672 |
De Minimis |
Arsenic compounds |
7440-38-2 |
|
178 |
Controlled PTE |
Beryllium compounds |
7440-41-7 |
|
15.7 |
Controlled PTE |
Cadmium compounds |
7440-43-9 |
|
23.3 |
Controlled PTE |
Chromium VI |
7440-47-3 |
|
40.9 |
Controlled PTE |
Chromium III |
16065-83-1 |
0.1 |
110 |
De Minimis |
Cobalt compounds |
7440-48-4 |
|
35.8 |
Controlled PTE |
Cyanide compounds |
57-12-5 |
4.86 |
4,320 |
De Minimis |
Lead compounds |
7439-92-1 |
|
219 |
Controlled PTE |
Manganese compounds |
7439-96-5 |
|
264 |
Controlled PTE |
Mercury compounds |
7439-97-6 |
0.162 |
144 |
De Minimis |
Nickel compounds |
7440-02-0 |
|
184 |
Controlled PTE |
Selenium compounds |
7782-49-2 |
10.8 |
9,600 |
De Minimis |
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 12)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the following records for a minimum of 5 years and make the records readily available to the District upon request.
(R3). These record keeping requirements shall be determined in accordance with the Title IV Phase II Acid Rain Permit and are specified in 40 CFR Part 75 Subpart F and 40 CFR Part 76, section 76.14.
(Regulation 6.47, section 3.4 and 3.5 referencing 40 CFR Parts 75 and 76)
1) Component-system identification code, as provided in 40 CFR
75.53 (including identification code for the moisture monitoring system, if applicable); (40 CFR 75.57(d)(1))
2) Date and hour; (40 CFR 75.57(d)(2))
3) Hourly average NOx concentration (ppm, rounded to the nearest tenth) and hourly average NOx concentration (ppm, rounded to the nearest tenth) adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(d)(3))
4) Hourly average diluent gas concentration (for NOx -diluent monitoring systems, only, in units of percent O2 or percent CO2, rounded to the nearest tenth); (40 CFR 75.57(d)(4))
5) If applicable, the hourly average moisture content of the stack gas (percent H2O, rounded to the nearest tenth). If the continuous moisture monitoring system consists of wet- and dry-basis oxygen analyzers, also record both the hourly wet- and dry-basis oxygen readings (in percent O2, rounded to the nearest tenth); (40 CFR 75.57(d)(5))
6) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth); (40 CFR 75.57(d)(6))
7) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d). The requirement to report hourly NOx emission rates to the nearest thousandth shall not affect NOx compliance determinations under part 76 of this chapter;
compliance with each applicable emission limit under part 76 shall be determined to the nearest hundredth pound per million Btu; (40 CFR 75.57(d)(7))
8) Percent monitoring system data availability (recorded to the nearest tenth of a percent), for the NOx -diluent or NOx concentration monitoring system, and, if applicable, for the moisture monitoring system, calculated pursuant to 40 CFR 75.32; (40 CFR 75.57(d)(8))
9) Method of determination for hourly average NOx emission rate or NOx concentration and (if applicable) for the hourly average moisture percentage, using Codes 1–55 in Table 4a of this section; and (40 CFR 75.57(d)(9))
10) Identification codes for emissions formulas used to derive hourly average NOx emission rate and total NOx mass emissions, as provided in 40 CFR 75.53, and (if applicable) the F-factor used to convert NOx concentrations into emission rates. (40 CFR 75.57(d)(10))
1) For SO2 concentration during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(1))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(1)(i))
(b) Date and hour; (40 CFR 75.57(c)(1)(ii))
(c) Hourly average SO2 concentration (ppm, rounded to the nearest tenth); (40 CFR 75.57(c)(1)(iii))
(d) Hourly average SO2 concentration (ppm, rounded to the nearest tenth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(1)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent), calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(1)(v))
(f) Method of determination for hourly average SO2 concentration using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(1)(vi))
2) For flow rate during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(2))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(2)(i))
(b) Date and hour; (40 CFR 75.57(c)(2)(ii))
(c) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand); (40 CFR 75.57(c)(2)(iii))
(d) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(2)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent) for the flow monitor, calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(2)(v))
(f) Method of determination for hourly average flow rate using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(2)(vi))
3) For SO2 mass emission rate during unit operation, as measured and reported from the certified primary monitoring system(s), certified redundant or non-redundant back-up monitoring system(s), or other approved method(s) of emissions determination: (40 CFR 75.57(c)(4))
(a) Date and hour; (40 CFR 75.57(c)(4)(i))
(b) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth); (40 CFR 75.57(c)(4)(ii))
(c) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); and (40 CFR 75.57(c)(4)(iii))
(d) Identification code for emissions formula used to derive hourly SO2 mass emission rate from SO2 concentration and flow and (if applicable) moisture data in paragraphs (c)(1), (c)(2), and (c)(3) of this section, as provided in 40 CFR 75.53. (40 CFR 75.57(c)(4)(iv))
1) Option 1: the owner or operator shall install, maintain, calibrate, and operate a PM CEMS for each steam generating unit. (Regulation 2.16, section 4.1.1) (See Comment 2) (40 CFR 64, See Comment 6)
(a) The use of PM CEMS as the measurement technique must be appropriate for the stack conditions.
(b) The PM CEMS must be installed, operated and maintained in accordance with the manufacturer’s recommendations.
(c) The PM CEMS must be certified in accordance with Performance Specification 11, Specifications and Test
Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources, found in 40 CFR 60, Appendix B.
(d) A quality assurance/quality control program must be implemented in accordance with procedures in 40 CFR 60, Appendix F, Procedure 2 (Quality Assurance Requirements for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources).
(e) Compliance with the particulate matter emission limit will be based upon three-hour rolling average periods during source operation.
(f) Quarterly excess emission reports must be submitted, and PM excess emissions shall be reported based upon three- hour rolling averages during source operation.
2) Option 2: the owner or operator shall conduct an annual EPA Reference Method 5 performance test following the testing requirements in Attachment B, Specific Condition b.ii.
3) The owner or operator shall keep records of which option was used to demonstrate compliance with PM standards.
1) The owner or operator shall monitor and record all PM emission data from PM CEMS, which is used as the indicator of normal operation of the PM control devices.
2) The owner or operator shall maintain daily records of any periods of time where the process was operating and the PM control devices were not operating or a declaration that the PM control devices operated at all times that day when the process was operating.
3) If there is any time that the PM control devices are bypassed or not in operation when the process is operating, then the owner or operator shall keep a record of the following for each bypass event:
(a) Date;
(b) Start time and stop time;
(c) Identification of the control devices and process equipment;
(d) PM emissions during the bypass in lb/hr;
(e) Summary of the cause or reason for each bypass event;
(f) Corrective action taken to minimize the extent or duration of the bypass event; and
(g) Measures implemented to prevent reoccurrence of the situation that resulted in the bypass event.
1) On a weekly basis, the owner or operator shall attempt to perform VE observations in accordance with procedures in EPA Method 9.
2) On the weeks when it is possible to collect unit-specific VE data, at least one hour of Method 9 data shall be collected for each unit.
3) Records of the Method 9 readings shall be submitted with the quarterly excess emission reports for PM emissions.
1) The owner or operator shall conduct a weekly one-minute visible emissions survey, during normal operation, of the PM Emission Points (stacks). For Emission Points without observed visible emissions during twelve consecutive operating weeks, the owner or operator may elect to conduct a monthly one-minute visible emission survey, during normal operation.
2) At Emission Points where visible emissions are observed, the owner or operator shall initiate corrective action within eight hours of the initial observation. If the visible emissions persist, the owner or operator shall perform or cause to be performed a Method 9 for stack emissions within 24 hours of the initial observation. If the opacity standard is exceeded, the owner or operator shall report the exceedance to the District, according to Regulation 1.07, and take all practicable steps to eliminate the exceedance.
3) The owner or operator shall maintain records, monthly, of the results of all visible emissions surveys and tests. Records of the results of any visible emissions survey shall include the date of the survey, the name of the person conducting the survey, whether or not visible emissions were observed, and what if any corrective action was performed. If an emission point is not being operated during a given month, then no visible emission survey needs to be performed and a negative declaration shall be entered in the record.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section. (See Comment 7)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
16.1. (Regulation 6.02, section 16.1)
1) For gaseous measurements, the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available electronically. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) For gaseous measurements the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available from the computer tape or cards. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Emission Unit ID number and emission point ID number;
2) The date and duration (including the start and stop time) during which a deviation occurred;
3) The magnitude of excess emissions;
4) Summary information on the cause or reason for excess emissions;
5) Corrective action taken to minimize the extent and duration of each excess emissions event;
6) Measures implemented to prevent reoccurrence of the situation that resulted in excess PM emissions; or
7) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and
span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
2) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
3) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Any deviation from the requirement to perform daily (or monthly, if required) visible emission surveys or Method 9 tests and documented reason;
2) Any deviation from the requirement to record the results of each VE survey and Method 9 test performed and documented reason;
3) The number, date, and time of each VE Survey where visible emissions were observed and the results of the Method 9 test performed;
4) Identification of all periods of exceeding an opacity standard;
5) Description of any corrective action taken for each exceedance of the opacity standard; or
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
The owner or operator shall identify all periods of exceeding an opacity standard during a quarterly reporting period. The report shall include the following:
1) Emission Unit ID number, Stack ID number, and/or Emission point ID number;
2) The beginning and ending date of the reporting period;
3) The date, time and results of each exceedance of the opacity standard;
4) Description of any corrective action taken for each exceedance.
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
U4 Comments
Plant-wide Summary |
All existing & new |
All new P/PE |
||
Industrial Total RC |
4.01 |
< 75 |
|
< 38 |
Non-Ind. Total RC |
4.01 |
< 7.5 |
|
< 3.8 |
Industrial Max. RNC |
0.10 |
< 3.0 |
|
|
Non-Ind. Max. RNC |
0.10 |
< 1.0 |
|
|
|
|
RNC Total |
U4 |
|
U5 |
|
U6 |
|
U11 |
|
U20 |
|
|
|
|
Indus. |
Non-Ind. |
Ind./Non-Ind. |
Ind./Non-Ind. |
Ind./Non-Ind. |
Ind./Non-Ind. |
Ind./Non-Ind. |
|||||
TAC |
CAS # |
RNC |
RNC |
RC |
RNC |
RC |
RNC |
RC |
RNC |
RC |
RNC |
RC |
RNC |
Total RC/ Max. RNC |
|
0.10 |
0.10 |
1.22 |
|
1.47 |
|
0.99 |
|
0.10 |
|
0.24 |
|
Arsenic and arsenic com |
7440-38-2 |
0.03 |
0.03 |
0.59 |
0.01 |
0.71 |
0.01 |
0.48 |
0.01 |
0.03 |
0.00 |
0.23 |
0.00 |
Cadmium and cadmium co |
7440-43-9 |
0.00 |
0.00 |
0.03 |
0.00 |
0.04 |
0.00 |
0.03 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Chromium hexavalent & C |
7440-47-3 |
0.01 |
0.01 |
0.37 |
0.00 |
0.45 |
0.00 |
0.30 |
0.00 |
0.07 |
0.00 |
0.00 |
0.00 |
Formaldehyde |
50-00-0 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Nickel and nickel compoun |
7440-02-0 |
0.03 |
0.03 |
0.04 |
0.01 |
0.04 |
0.01 |
0.03 |
0.01 |
0.00 |
0.00 |
0.00 |
0.00 |
Cobalt and cobalt compou |
7440-48-4 |
0.01 |
0.01 |
0.07 |
0.00 |
0.08 |
0.00 |
0.06 |
0.00 |
0.00 |
0.00 |
0.01 |
0.00 |
Hydrochloric acid [Hydrog |
7647-01-0 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Hydrofluoric acid [Hydrog |
7664-39-3 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Lead compounds1 |
7439-92-1 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Manganese and Mangane |
7439-96-5 |
0.02 |
0.02 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.01 |
0.00 |
0.00 |
Acrolein |
107-02-8 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Beryllium and beryllium co |
7440-41-7 |
0.00 |
0.00 |
0.03 |
0.00 |
0.03 |
0.00 |
0.02 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Ethylene dibromide [1,2-D |
106-93-4 |
0.00 |
0.00 |
0.02 |
0.00 |
0.02 |
0.00 |
0.01 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Ethylene dichloride [1,2-D |
107-06-2 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Dimethyl sulfate |
77-78-1 |
0.00 |
0.00 |
0.06 |
0.00 |
0.07 |
0.00 |
0.05 |
0.00 |
0.00 |
0.00 |
0.00 |
0.00 |
Methylhydrazine |
60-34-4 |
0.10 |
0.10 |
0.01 |
0.03 |
0.01 |
0.04 |
0.01 |
0.03 |
0.00 |
0.00 |
0.00 |
0.00 |
January 1st through March 31th May 30th April 1st through June 30th August 29th
July 1st through September 30th November 29th October 1st through December 31st March 1st
(40 CFR 63.6(i)(4)(i)). The compliance date for the EGUs at this plant is November 1, 2015.
D.C. Circuit to lift the stay of the Cross State Air Pollution Rule. While the Court considers the motion, CAIR remains in place and no immediate action from States or affected sources is expected.
Emission Unit U5: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 5
U5 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.02 |
Emission Monitoring for Existing Sources |
1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18 |
6.07 |
Standards of Performance for Existing Indirect Heat Exchangers |
1, 2, 3, 4 |
6.09 |
Standards of Performance for Existing Process Operations |
1, 2, 3, 5 |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound- and Nitrogen Oxides-Emitting Facilities |
1, 2, 3, 4, 5 |
6.47 |
Federal Acid Rain Program for Existing Sources Incorporated by Reference |
1, 2, 3, 4, 5 |
7.08 |
Standards of Performance for New Process Operations |
1, 2, 3, 4, 5, 6 |
40 CFR 64 |
Compliance Assurance Monitoring for Major Stationary Sources |
64.1 through 64.10 |
40 CFR 72 |
Permits Regulation |
Subparts A, B, C, D, E, F, G, H, I |
40 CFR 73 |
Sulfur Dioxide Allowance System |
Subparts A, B, C, D, E, F, G |
40 CFR 75 |
Continuous Emission Monitoring |
Subparts A, B, C, D, E, F, G |
40 CFR 76 |
Acid Rain Nitrogen Oxides Emission Reduction Program |
76.1, 76.2, 76.3, 76.4, 76.5, 76.7, 76.8, 76.9, 76.11, 76.13, 76.14, 76.15, Appendix A, Appendix B |
40 CFR 77 |
Excess Emissions |
77.1, 77.2, 77.3, 77.4, 77.5, 77.6 |
40 CFR 78 |
Appeals Procedures for Acid Rain Program |
78.1, 78.2, 78.3, 78.4, 78.5, 78.6, 78.8, 78.9, 78.10, 78.11, 78.13, 78.14, 78.15, 78.16, 78.17, 78.18, 78.19, 78.20 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U5 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
|
One (1) dry bottom wall-fired boiler with |
5.00, 5.01, 5.02, 5.14, |
|
|
E3 |
low NOx burner, make Riley Stoker, model 3469 Type Reheat, nominal rating 1,875 MMBtu/hr, using pulverized coal as the primary fuel and natural gas as the |
5.20, 5.21, 5.22, 5.23, 6.02, 6.07, 6.42, 6.47, 40 CFR 64, 40 CFR 72-78 |
C3, C4 |
S5 |
|
secondary fuel. |
|
|
|
|
Three (3) coal silos, make American Air |
5.00, 5.01, 5.02, 5.14, |
|
|
E4 |
Filter, model Type D, controlled by centrifugal dust collector and equipped with three (3) coal mills, make CE |
5.20, 5.21, 5.22, 5.23, 6.09, 7.08 |
C8 |
S2 |
|
(Raymond), model 763 Type “RS” Bowl |
|
|
|
|
Mills. |
|
|
|
Note: The owner or operator shall shut down this unit (U5) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U5 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C3 |
One (1) custom-built electrostatic precipitator (ESP) for PM control, make Southern Environmental, model Custom Built. |
PM emission data from PM CEMS (if PM CEMS is not used to demonstrate compliance) |
S5 |
C4 |
One (1) Flue Gas Desulfurization (FGD) for SO2 control, make American Air Filter/Burns & McDonnel, model Custom Built |
N/A (See Comment 9) |
|
C8 |
One (1) dry centrifugal dust collector, make American Air Filter, model Type D. |
N/A (See Comment 4) |
S2 |
U5 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
Compliance Options |
PM |
Opacity |
Control Device Performance indication |
Option 1 |
Certified PM CEMS |
Weekly VE/Method 9, or Certified COMS |
N/A (See Comment 9) |
Option 2 |
Annual testing |
Weekly VE/Method 9, or Certified COMS |
PM CEMS |
5.00 and 5.21) (See Comment 5)
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Biphenyl |
92-52-4 |
0.232 |
206 |
De Minimis |
Naphthalene |
91-20-3 |
0.016 |
13.9 |
De Minimis |
Acetaldehyde |
75-07-0 |
0.243 |
216 |
De Minimis |
Acetophenone |
98-86-2 |
189 |
168,000 |
De Minimis |
Acrolein (Propenal) |
107-02-8 |
|
31.2 |
Controlled PTE |
Benzene |
71-43-2 |
0.24 |
216 |
De Minimis |
Benzyl Chloride |
100-44-7 |
0.011 |
9.6 |
De Minimis |
Bis(2-ethylhexyl)phthalate (DEHP) (DOP) |
117-81-7 |
0.23 |
202 |
De Minimis |
Bromoform |
75-25-2 |
0.49 |
437 |
De Minimis |
Carbon disulfide |
75-15-0 |
378 |
336,000 |
De Minimis |
2-Chloroacetophenone |
532-27-4 |
0.016 |
14.4 |
De Minimis |
Chlorobenzene |
108-90-7 |
540 |
480,000 |
De Minimis |
Chloroform |
67-66-3 |
0.023 |
20.6 |
De Minimis |
Cumene |
98-82-8 |
0.054 |
48 |
De Minimis |
Dimethyl sulfate |
77-78-1 |
|
37.2 |
Controlled PTE |
2,4-Dinitrotoluene |
121-14-2 |
0.0059 |
5.28 |
De Minimis |
Ethyl benzene |
100-41-4 |
0.22 |
192 |
De Minimis |
Ethyl chloride |
75-00-3 |
54 |
48,000 |
De Minimis |
Ethylene dichloride |
107-06-2 |
|
31.0 |
Controlled PTE |
Ethylene dibromide |
106-93-4 |
|
42.7 |
Controlled PTE |
Formaldehyde |
50-00-0 |
|
42.7 |
Controlled PTE |
Hexane |
110-54-3 |
378 |
336,000 |
De Minimis |
Isophorone |
78-59-1 |
2.00 |
1,776 |
De Minimis |
Methyl bromide |
74-83-9 |
2.7 |
2,400 |
De Minimis |
Methyl chloride |
74-87-3 |
48.6 |
43,200 |
De Minimis |
Methyl hydrazine |
60-34-4 |
|
132 |
Controlled PTE |
Methyl methacrylate |
80-62-6 |
378 |
336,000 |
De Minimis |
Methyl-tert-butylether |
1634-04-4 |
2.079 |
1,848 |
De Minimis |
Methylene chloride |
75-09-2 |
54 |
48,000 |
De Minimis |
Phenol |
108-95-2 |
108 |
96,000 |
De Minimis |
Propionaldehyde |
123-38-6 |
4.32 |
3,840 |
De Minimis |
Styrene |
100-42-5 |
0.918 |
816 |
De Minimis |
Tetrachloroethylene (Perc) |
127-18-4 |
2.079 |
1,848 |
De Minimis |
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Toluene |
108-88-3 |
2700 |
2,400,000 |
De Minimis |
Xylene |
1330-20-7 |
54 |
48,000 |
De Minimis |
Vinyl Acetate |
108-05-4 |
171.72 |
152,640 |
De Minimis |
Hydrochloric acid |
7647-01-0 |
|
16,580 |
Controlled PTE |
Hydrogen fluoride |
7664-39-3 |
|
7,903 |
Controlled PTE |
Antimony compounds |
7440-36-0 |
0.756 |
672 |
De Minimis |
Arsenic compounds |
7440-38-2 |
|
204 |
Controlled PTE |
Beryllium compounds |
7440-41-7 |
|
17.9 |
Controlled PTE |
Cadmium compounds |
7440-43-9 |
|
26.7 |
Controlled PTE |
Chromium VI |
7440-47-3 |
|
46.8 |
Controlled PTE |
Chromium III |
16065-83-1 |
0.1 |
110 |
De Minimis |
Cobalt compounds |
7440-48-4 |
|
40.9 |
Controlled PTE |
Cyanide compounds |
57-12-5 |
4.86 |
4,320 |
De Minimis |
Lead compounds |
7439-92-1 |
|
250 |
Controlled PTE |
Manganese compounds |
7439-96-5 |
|
301 |
Controlled PTE |
Mercury compounds |
7439-97-6 |
0.162 |
144 |
De Minimis |
Nickel compounds |
7440-02-0 |
|
210 |
Controlled PTE |
Selenium compounds |
7782-49-2 |
10.8 |
9,600 |
De Minimis |
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 12)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the following records for a minimum of 5 years and make the records readily available to the District upon request.
(R3). These record keeping requirements shall be determined in accordance with the Title IV Phase II Acid Rain Permit and are specified in 40 CFR Part 75 Subpart F and 40 CFR Part 76, section 76.14.
(Regulation 6.47, section 3.4 and 3.5 referencing 40 CFR Parts 75 and 76)
1) Component-system identification code, as provided in 40 CFR
75.53 (including identification code for the moisture monitoring system, if applicable); (40 CFR 75.57(d)(1))
2) Date and hour; (40 CFR 75.57(d)(2))
3) Hourly average NOx concentration (ppm, rounded to the nearest tenth) and hourly average NOx concentration (ppm, rounded to the nearest tenth) adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(d)(3))
4) Hourly average diluent gas concentration (for NOx -diluent monitoring systems, only, in units of percent O2 or percent CO2, rounded to the nearest tenth); (40 CFR 75.57(d)(4))
5) If applicable, the hourly average moisture content of the stack gas (percent H2O, rounded to the nearest tenth). If the continuous moisture monitoring system consists of wet- and dry-basis oxygen analyzers, also record both the hourly wet- and dry-basis oxygen readings (in percent O2, rounded to the nearest tenth); (40 CFR 75.57(d)(5))
6) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth); (40 CFR 75.57(d)(6))
7) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d). The requirement to report hourly NOx emission rates to the nearest thousandth shall not affect NOx compliance determinations under part 76 of this chapter;
compliance with each applicable emission limit under part 76 shall be determined to the nearest hundredth pound per million Btu; (40 CFR 75.57(d)(7))
8) Percent monitoring system data availability (recorded to the nearest tenth of a percent), for the NOx -diluent or NOx concentration monitoring system, and, if applicable, for the moisture monitoring system, calculated pursuant to 40 CFR 75.32; (40 CFR 75.57(d)(8))
9) Method of determination for hourly average NOx emission rate or NOx concentration and (if applicable) for the hourly average moisture percentage, using Codes 1–55 in Table 4a of this section; and (40 CFR 75.57(d)(9))
10) Identification codes for emissions formulas used to derive hourly average NOx emission rate and total NOx mass emissions, as provided in 40 CFR 75.53, and (if applicable) the F-factor used to convert NOx concentrations into emission rates. (40 CFR 75.57(d)(10))
1) For SO2 concentration during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(1))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(1)(i))
(b) Date and hour; (40 CFR 75.57(c)(1)(ii))
(c) Hourly average SO2 concentration (ppm, rounded to the nearest tenth); (40 CFR 75.57(c)(1)(iii))
(d) Hourly average SO2 concentration (ppm, rounded to the nearest tenth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(1)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent), calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(1)(v))
(f) Method of determination for hourly average SO2 concentration using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(1)(vi))
2) For flow rate during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(2))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(2)(i))
(b) Date and hour; (40 CFR 75.57(c)(2)(ii))
(c) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand); (40 CFR 75.57(c)(2)(iii))
(d) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(2)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent) for the flow monitor, calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(2)(v))
(f) Method of determination for hourly average flow rate using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(2)(vi))
3) For SO2 mass emission rate during unit operation, as measured and reported from the certified primary monitoring system(s), certified redundant or non-redundant back-up monitoring system(s), or other approved method(s) of emissions determination: (40 CFR 75.57(c)(4))
(a) Date and hour; (40 CFR 75.57(c)(4)(i))
(b) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth); (40 CFR 75.57(c)(4)(ii))
(c) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); and (40 CFR 75.57(c)(4)(iii))
(d) Identification code for emissions formula used to derive hourly SO2 mass emission rate from SO2 concentration and flow and (if applicable) moisture data in paragraphs (c)(1), (c)(2), and (c)(3) of this section, as provided in 40 CFR 75.53. (40 CFR 75.57(c)(4)(iv))
1) Option 1: the owner or operator shall install, maintain, calibrate, and operate a PM CEMS for each steam generating unit. (Regulation 2.16, section 4.1.1) (See Comment 2) (40 CFR 64, See Comment 6)
(a) The use of PM CEMS as the measurement technique must be appropriate for the stack conditions.
(b) The PM CEMS must be installed, operated and maintained in accordance with the manufacturer’s recommendations.
(c) The PM CEMS must be certified in accordance with Performance Specification 11, Specifications and Test
Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources, found in 40 CFR 60, Appendix B.
(d) A quality assurance/quality control program must be implemented in accordance with procedures in 40 CFR 60, Appendix F, Procedure 2 (Quality Assurance Requirements for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources).
(e) Compliance with the particulate matter emission limit will be based upon three-hour rolling average periods during source operation.
(f) Quarterly excess emission reports must be submitted, and PM excess emissions shall be reported based upon three- hour rolling averages during source operation.
2) Option 2: the owner or operator shall conduct an annual EPA Reference Method 5 performance test following the testing requirements in Attachment B, Specific Condition b.ii.
3) The owner or operator shall keep records of which option was used to demonstrate compliance with PM standards.
1) The owner or operator shall monitor and record all PM emission data from PM CEMS, which is used as the indicator of normal operation of the PM control devices.
2) The owner or operator shall maintain daily records of any periods of time where the process was operating and the PM control devices were not operating or a declaration that the PM control devices operated at all times that day when the process was operating.
3) If there is any time that the PM control devices are bypassed or not in operation when the process is operating, then the owner or operator shall keep a record of the following for each bypass event:
(a) Date;
(b) Start time and stop time;
(c) Identification of the control devices and process equipment;
(d) PM emissions during the bypass in lb/hr;
(e) Summary of the cause or reason for each bypass event;
(f) Corrective action taken to minimize the extent or duration of the bypass event; and
(g) Measures implemented to prevent reoccurrence of the situation that resulted in the bypass event.
1) On a weekly basis, the owner or operator shall attempt to perform VE observations in accordance with procedures in EPA Method 9.
2) On the weeks when it is possible to collect unit-specific VE data, at least one hour of Method 9 data shall be collected for each unit.
3) Records of the Method 9 readings shall be submitted with the quarterly excess emission reports for PM emissions.
1) The owner or operator shall conduct a weekly one-minute visible emissions survey, during normal operation, of the PM Emission Points (stacks). For Emission Points without observed visible emissions during twelve consecutive operating weeks, the owner or operator may elect to conduct a monthly one-minute visible emission survey, during normal operation.
2) At Emission Points where visible emissions are observed, the owner or operator shall initiate corrective action within eight hours of the initial observation. If the visible emissions persist, the owner or operator shall perform or cause to be performed a Method 9 for stack emissions within 24 hours of the initial observation. If the opacity standard is exceeded, the owner or operator shall report the exceedance to the District, according to Regulation 1.07, and take all practicable steps to eliminate the exceedance.
3) The owner or operator shall maintain records, monthly, of the results of all visible emissions surveys and tests. Records of the results of any visible emissions survey shall include the date of the survey, the name of the person conducting the survey, whether or not visible emissions were observed, and what if any corrective action was performed. If an emission point is not being operated during a given month, then no visible emission survey needs to be performed and a negative declaration shall be entered in the record.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section. (See Comment 7)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
16.1. (Regulation 6.02, section 16.1)
1) For gaseous measurements, the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available electronically. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
submitted as specified in Subpart G – reporting requirements. (See Attachment D)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) For gaseous measurements the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available from the computer tape or cards. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted,
such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Emission Unit ID number and emission point ID number;
2) The date and duration (including the start and stop time) during which a deviation occurred;
3) The magnitude of excess emissions;
4) Summary information on the cause or reason for excess emissions;
5) Corrective action taken to minimize the extent and duration of each excess emissions event;
6) Measures implemented to prevent reoccurrence of the situation that resulted in excess PM emissions; or
7) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
2) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
3) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Any deviation from the requirement to perform daily (or monthly, if required) visible emission surveys or Method 9 tests and documented reason;
2) Any deviation from the requirement to record the results of each VE survey and Method 9 test performed and documented reason;
3) The number, date, and time of each VE Survey where visible emissions were observed and the results of the Method 9 test performed;
4) Identification of all periods of exceeding an opacity standard;
5) Description of any corrective action taken for each exceedance of the opacity standard; or
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
Attachment D) (Regulation 6.47, section 3.4 and 3.5 referencing 40 CFR
Parts 75 and 76)
The owner or operator shall identify all periods of exceeding an opacity standard during a quarterly reporting period. The report shall include the following:
1) Emission Unit ID number, Stack ID number, and/or Emission point ID number;
2) The beginning and ending date of the reporting period;
3) The date, time and results of each exceedance of the opacity standard;
4) Description of any corrective action taken for each exceedance.
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
U5 Comments
January 1st through March 31th May 30th April 1st through June 30th August 29th
July 1st through September 30th November 29th
October 1st through December 31st March 1st
D.C. Circuit to lift the stay of the Cross State Air Pollution Rule. While the Court considers the motion, CAIR remains in place and no immediate action from States or affected sources is expected.
Emission Unit U6: Electric Utility Steam Generating Unit (EGU) and Coal Silos – EGU 6
U6 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.02 |
Emission Monitoring for Existing Sources |
1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18 |
6.07 |
Standards of Performance for Existing Indirect Heat Exchangers |
1, 2, 3, 4 |
6.09 |
Standards of Performance for Existing Process Operations |
1, 2, 3, 5 |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound- and Nitrogen Oxides-Emitting Facilities |
1, 2, 3, 4, 5 |
6.47 |
Federal Acid Rain Program for Existing Sources Incorporated by Reference |
1, 2, 3, 4, 5 |
40 CFR 64 |
Compliance Assurance Monitoring for Major Stationary Sources |
64.1 through 64.10 |
40 CFR 72 |
Permits Regulation |
Subparts A, B, C, D, E, F, G, H, I |
40 CFR 73 |
Sulfur Dioxide Allowance System |
Subparts A, B, C, D, E, F, G |
40 CFR 75 |
Continuous Emission Monitoring |
Subparts A, B, C, D, E, F, G |
40 CFR 76 |
Acid Rain Nitrogen Oxides Emission Reduction Program |
76.1, 76.2, 76.3, 76.4, 76.5, 76.7, 76.8, 76.9, 76.11, 76.13, 76.14, 76.15, Appendix A, Appendix B |
40 CFR 77 |
Excess Emissions |
77.1, 77.2, 77.3, 77.4, 77.5, 77.6 |
40 CFR 78 |
Appeals Procedures for Acid Rain Program |
78.1, 78.2, 78.3, 78.4, 78.5, 78.6, 78.8, 78.9, 78.10, 78.11, 78.13, 78.14, 78.15, 78.16, 78.17, 78.18, 78.19, 78.20 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U6 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
|
One (1) tangentially fired boiler with low |
5.00, 5.01, 5.02, 5.14, |
|
|
E5 |
NOx burner, make Combustion Engineering, model Type CCRR, nominal rating 2,453 MMBtu/hr, using pulverized coal as the primary fuel and natural gas as |
5.20, 5.21, 5.22, 5.23, 6.02, 6.07, 6.42, 6.47, 40 CFR 64, 40 CFR 72-78 |
C5, C6 |
S6 |
|
the secondary fuel. |
|
|
|
|
Five (5) coal silos, make American Air |
5.00, 5.01, 5.02, 5.14, |
|
|
E6 |
Filter, model Type D, controlled by centrifugal dust collector and equipped with five (5) coal mills, make CE |
5.20, 5.21, 5.22, 5.23, 6.09 |
C9 |
S3 |
|
(Raymond), model 703 Type “RS” Bowl |
|
|
|
|
Mills. |
|
|
|
Note: The owner or operator shall shut down this unit (U6) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U6 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C5 |
One (1) custom-built electrostatic precipitator (ESP), make Buell |
PM emission data from PM CEMS (if PM CEMS is not used to demonstrate compliance) |
S6 |
ID |
Description |
Performance Indicator |
Stack ID |
C6 |
One (1) Flue Gas Desulfurization (FGD) unit for SO2 control using limestone scrubbing liquor, CEA/Burns & McDonnel |
N/A (See Comment 9) |
|
C9 |
One (1) centrifugal dust collector, make American Air Filter, model Type D |
N/A (See Comment 4) |
S3 |
U6 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
Compliance Options |
PM |
Opacity |
Control Device Performance indication |
Option 1 |
Certified PM CEMS |
Weekly VE/Method 9, or Certified COMS |
N/A (See Comment 9) |
Option 2 |
Annual testing |
Weekly VE/Method 9, or Certified COMS |
PM CEMS |
5.00 and 5.21) (See Comment 5)
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Biphenyl |
92-52-4 |
0.232 |
206 |
De Minimis |
Naphthalene |
91-20-3 |
0.016 |
13.9 |
De Minimis |
Acetaldehyde |
75-07-0 |
0.243 |
216 |
De Minimis |
Acetophenone |
98-86-2 |
189 |
168,000 |
De Minimis |
Acrolein (Propenal) |
107-02-8 |
|
40.8 |
Controlled PTE |
Benzene |
71-43-2 |
0.24 |
216 |
De Minimis |
Benzyl Chloride |
100-44-7 |
0.011 |
9.6 |
De Minimis |
Bis(2-ethylhexyl)phthalate (DEHP) (DOP) |
117-81-7 |
0.23 |
202 |
De Minimis |
Bromoform |
75-25-2 |
0.49 |
437 |
De Minimis |
Carbon disulfide |
75-15-0 |
378 |
336,000 |
De Minimis |
2-Chloroacetophenone |
532-27-4 |
0.016 |
14.4 |
De Minimis |
Chlorobenzene |
108-90-7 |
540 |
480,000 |
De Minimis |
Chloroform |
67-66-3 |
0.023 |
20.6 |
De Minimis |
Cumene |
98-82-8 |
0.054 |
48 |
De Minimis |
Dimethyl sulfate |
77-78-1 |
|
48.7 |
Controlled PTE |
2,4-Dinitrotoluene |
121-14-2 |
0.0059 |
5.28 |
De Minimis |
Ethyl benzene |
100-41-4 |
0.22 |
192 |
De Minimis |
Ethyl chloride |
75-00-3 |
54 |
48,000 |
De Minimis |
Ethylene dichloride |
107-06-2 |
|
40.5 |
Controlled PTE |
Ethylene dibromide |
106-93-4 |
|
55.9 |
Controlled PTE |
Formaldehyde |
50-00-0 |
|
55.9 |
Controlled PTE |
Hexane |
110-54-3 |
378 |
336,000 |
De Minimis |
Isophorone |
78-59-1 |
2.00 |
1,776 |
De Minimis |
Methyl bromide |
74-83-9 |
2.7 |
2,400 |
De Minimis |
Methyl chloride |
74-87-3 |
48.6 |
43,200 |
De Minimis |
Methyl hydrazine |
60-34-4 |
|
172 |
Controlled PTE |
Methyl methacrylate |
80-62-6 |
378 |
336,000 |
De Minimis |
Methyl-tert-butylether |
1634-04-4 |
2.079 |
1,848 |
De Minimis |
Methylene chloride |
75-09-2 |
54 |
48,000 |
De Minimis |
Phenol |
108-95-2 |
108 |
96,000 |
De Minimis |
Propionaldehyde |
123-38-6 |
4.32 |
3,840 |
De Minimis |
Styrene |
100-42-5 |
0.918 |
816 |
De Minimis |
Tetrachloroethylene (Perc) |
127-18-4 |
2.079 |
1,848 |
De Minimis |
TAC Name |
CAS # |
TAC Limits Determination |
||
(lbs/hr) |
(lbs/yr) |
Basis of Limits |
||
Toluene |
108-88-3 |
2700 |
2,400,000 |
De Minimis |
Xylene |
1330-20-7 |
54 |
48,000 |
De Minimis |
Vinyl Acetate |
108-05-4 |
171.72 |
152,640 |
De Minimis |
Hydrochloric acid |
7647-01-0 |
|
21,732 |
Controlled PTE |
Hydrogen fluoride |
7664-39-3 |
|
10,349 |
Controlled PTE |
Antimony compounds |
7440-36-0 |
0.756 |
672 |
De Minimis |
Arsenic compounds |
7440-38-2 |
|
266 |
Controlled PTE |
Beryllium compounds |
7440-41-7 |
|
23.4 |
Controlled PTE |
Cadmium compounds |
7440-43-9 |
|
34.9 |
Controlled PTE |
Chromium VI |
7440-47-3 |
|
61.2 |
Controlled PTE |
Chromium III |
16065-83-1 |
|
140 |
Controlled PTE |
Cobalt compounds |
7440-48-4 |
|
53.6 |
Controlled PTE |
Cyanide compounds |
57-12-5 |
4.86 |
4,320 |
De Minimis |
Lead compounds |
7439-92-1 |
|
328 |
Controlled PTE |
Manganese compounds |
7439-96-5 |
|
394 |
Controlled PTE |
Mercury compounds |
7439-97-6 |
0.162 |
144 |
De Minimis |
Nickel compounds |
7440-02-0 |
|
275 |
Controlled PTE |
Selenium compounds |
7782-49-2 |
10.8 |
9,600 |
De Minimis |
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 12)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the following records for a minimum of 5 years and make the records readily available to the District upon request.
(R3). These record keeping requirements shall be determined in accordance with the Title IV Phase II Acid Rain Permit and are specified in 40 CFR Part 75 Subpart F and 40 CFR Part 76, section 76.14.
(Regulation 6.47, section 3.4 and 3.5 referencing 40 CFR Parts 75 and 76)
1) Component-system identification code, as provided in 40 CFR
75.53 (including identification code for the moisture monitoring system, if applicable); (40 CFR 75.57(d)(1))
2) Date and hour; (40 CFR 75.57(d)(2))
3) Hourly average NOx concentration (ppm, rounded to the nearest tenth) and hourly average NOx concentration (ppm, rounded to the nearest tenth) adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(d)(3))
4) Hourly average diluent gas concentration (for NOx -diluent monitoring systems, only, in units of percent O2 or percent CO2, rounded to the nearest tenth); (40 CFR 75.57(d)(4))
5) If applicable, the hourly average moisture content of the stack gas (percent H2O, rounded to the nearest tenth). If the continuous moisture monitoring system consists of wet- and dry-basis oxygen analyzers, also record both the hourly wet- and dry-basis oxygen readings (in percent O2, rounded to the nearest tenth); (40 CFR 75.57(d)(5))
6) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth); (40 CFR 75.57(d)(6))
7) Hourly average NOx emission rate (for NOx -diluent monitoring systems only, in units of lb/mmBtu, rounded to the nearest thousandth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d). The requirement to report hourly NOx emission rates to the nearest thousandth shall not affect NOx compliance determinations under part 76 of this chapter;
compliance with each applicable emission limit under part 76 shall be determined to the nearest hundredth pound per million Btu; (40 CFR 75.57(d)(7))
8) Percent monitoring system data availability (recorded to the nearest tenth of a percent), for the NOx -diluent or NOx concentration monitoring system, and, if applicable, for the moisture monitoring system, calculated pursuant to 40 CFR 75.32; (40 CFR 75.57(d)(8))
9) Method of determination for hourly average NOx emission rate or NOx concentration and (if applicable) for the hourly average moisture percentage, using Codes 1–55 in Table 4a of this section; and (40 CFR 75.57(d)(9))
10) Identification codes for emissions formulas used to derive hourly average NOx emission rate and total NOx mass emissions, as provided in 40 CFR 75.53, and (if applicable) the F-factor used to convert NOx concentrations into emission rates. (40 CFR 75.57(d)(10))
1) For SO2 concentration during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(1))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(1)(i))
(b) Date and hour; (40 CFR 75.57(c)(1)(ii))
(c) Hourly average SO2 concentration (ppm, rounded to the nearest tenth); (40 CFR 75.57(c)(1)(iii))
(d) Hourly average SO2 concentration (ppm, rounded to the nearest tenth), adjusted for bias if bias adjustment factor is required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(1)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent), calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(1)(v))
(f) Method of determination for hourly average SO2 concentration using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(1)(vi))
2) For flow rate during unit operation, as measured and reported from each certified primary monitor, certified back-up monitor, or other approved method of emissions determination: (40 CFR 75.57(c)(2))
(a) Component-system identification code, as provided in 40 CFR 75.53; (40 CFR 75.57(c)(2)(i))
(b) Date and hour; (40 CFR 75.57(c)(2)(ii))
(c) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand); (40 CFR 75.57(c)(2)(iii))
(d) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); (40 CFR 75.57(c)(2)(iv))
(e) Percent monitor data availability (recorded to the nearest tenth of a percent) for the flow monitor, calculated pursuant to 40 CFR 75.32; and (40 CFR 75.57(c)(2)(v))
(f) Method of determination for hourly average flow rate using Codes 1–55 in Table 4a of this section. (40 CFR 75.57(c)(2)(vi))
3) For SO2 mass emission rate during unit operation, as measured and reported from the certified primary monitoring system(s), certified redundant or non-redundant back-up monitoring system(s), or other approved method(s) of emissions determination: (40 CFR 75.57(c)(4))
(a) Date and hour; (40 CFR 75.57(c)(4)(i))
(b) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth); (40 CFR 75.57(c)(4)(ii))
(c) Hourly SO2 mass emission rate (lb/hr, rounded to the nearest tenth), adjusted for bias if bias adjustment factor required, as provided in 40 CFR 75.24(d); and (40 CFR 75.57(c)(4)(iii))
(d) Identification code for emissions formula used to derive hourly SO2 mass emission rate from SO2 concentration and flow and (if applicable) moisture data in paragraphs (c)(1), (c)(2), and (c)(3) of this section, as provided in 40 CFR 75.53. (40 CFR 75.57(c)(4)(iv))
1) Option 1: the owner or operator shall install, maintain, calibrate, and operate a PM CEMS for each steam generating unit. (Regulation 2.16, section 4.1.1) (See Comment 2) (40 CFR 64, See Comment 6)
(a) The use of PM CEMS as the measurement technique must be appropriate for the stack conditions.
(b) The PM CEMS must be installed, operated and maintained in accordance with the manufacturer’s recommendations.
(c) The PM CEMS must be certified in accordance with Performance Specification 11, Specifications and Test
Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources, found in 40 CFR 60, Appendix B.
(d) A quality assurance/quality control program must be implemented in accordance with procedures in 40 CFR 60, Appendix F, Procedure 2 (Quality Assurance Requirements for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources).
(e) Compliance with the particulate matter emission limit will be based upon three-hour rolling average periods during source operation.
(f) Quarterly excess emission reports must be submitted, and PM excess emissions shall be reported based upon three- hour rolling averages during source operation.
2) Option 2: the owner or operator shall conduct an annual EPA Reference Method 5 performance test following the testing requirements in Attachment B, Specific Condition b.ii.
3) The owner or operator shall keep records of which option was used to demonstrate compliance with PM standards.
1) The owner or operator shall monitor and record all PM emission data from PM CEMS, which is used as the indicator of normal operation of the PM control devices.
2) The owner or operator shall maintain daily records of any periods of time where the process was operating and the PM control devices were not operating or a declaration that the PM control devices operated at all times that day when the process was operating.
3) If there is any time that the PM control devices are bypassed or not in operation when the process is operating, then the owner or operator shall keep a record of the following for each bypass event:
(a) Date;
(b) Start time and stop time;
(c) Identification of the control devices and process equipment;
(d) PM emissions during the bypass in lb/hr;
(e) Summary of the cause or reason for each bypass event;
(f) Corrective action taken to minimize the extent or duration of the bypass event; and
(g) Measures implemented to prevent reoccurrence of the situation that resulted in the bypass event.
1) On a weekly basis, the owner or operator shall attempt to perform VE observations in accordance with procedures in EPA Method 9.
2) On the weeks when it is possible to collect unit-specific VE data, at least one hour of Method 9 data shall be collected for each unit.
3) Records of the Method 9 readings shall be submitted with the quarterly excess emission reports for PM emissions.
1) The owner or operator shall conduct a weekly one-minute visible emissions survey, during normal operation, of the PM Emission Points (stacks). For Emission Points without observed visible emissions during twelve consecutive operating weeks, the owner or operator may elect to conduct a monthly one-minute visible emission survey, during normal operation.
2) At Emission Points where visible emissions are observed, the owner or operator shall initiate corrective action within eight hours of the initial observation. If the visible emissions persist, the owner or operator shall perform or cause to be performed a Method 9 for stack emissions within 24 hours of the initial observation. If the opacity standard is exceeded, the owner or operator shall report the exceedance to the District, according to Regulation 1.07, and take all practicable steps to eliminate the exceedance.
3) The owner or operator shall maintain records, monthly, of the results of all visible emissions surveys and tests. Records of the results of any visible emissions survey shall include the date of the survey, the name of the person conducting the survey, whether or not visible emissions were observed, and what if any corrective action was performed. If an emission point is not being operated during a given month, then no visible emission survey needs to be performed and a negative declaration shall be entered in the record.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section. (See Comment 7)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
16.1. (Regulation 6.02, section 16.1)
1) For gaseous measurements, the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available electronically. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
submitted as specified in Subpart G – reporting requirements. (See Attachment D)
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) For gaseous measurements the summary shall consist of hourly averages in the units of the applicable standard. The hourly averages shall not appear in the written summary, but shall be made available from the computer tape or cards. (Regulation 6.02, section 16.3)
2) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
3) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted,
such information shall be included in the report. (Regulation 6.02, section 16.5)
4) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Emission Unit ID number and emission point ID number;
2) The date and duration (including the start and stop time) during which a deviation occurred;
3) The magnitude of excess emissions;
4) Summary information on the cause or reason for excess emissions;
5) Corrective action taken to minimize the extent and duration of each excess emissions event;
6) Measures implemented to prevent reoccurrence of the situation that resulted in excess PM emissions; or
7) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) The data and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of system repairs or adjustment shall be reported. Proof of continuous monitoring system performance whenever system repairs or adjustments have been made is required. (Regulation 6.02, section 16.4)
2) When no excess emissions have occurred and the continuous monitoring systems have been inoperative, repaired, or adjusted, such information shall be included in the report. (Regulation 6.02, section 16.5)
3) Owners or operators of affected facilities shall maintain a file of all information reported in the quarterly summaries, and all other data collected either by the continuous monitoring system or as necessary to convert monitoring data to the units of the applicable standard for a minimum of two years from the date of collection of such data or submission of such summaries. (Regulation 6.02, section 16.6)
1) Any deviation from the requirement to perform daily (or monthly, if required) visible emission surveys or Method 9 tests and documented reason;
2) Any deviation from the requirement to record the results of each VE survey and Method 9 test performed and documented reason;
3) The number, date, and time of each VE Survey where visible emissions were observed and the results of the Method 9 test performed;
4) Identification of all periods of exceeding an opacity standard;
5) Description of any corrective action taken for each exceedance of the opacity standard; or
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
Attachment D) (Regulation 6.47, section 3.4 and 3.5 referencing 40 CFR
Parts 75 and 76)
The owner or operator shall identify all periods of exceeding an opacity standard during a quarterly reporting period. The report shall include the following:
1) Emission Unit ID number, Stack ID number, and/or Emission point ID number;
2) The beginning and ending date of the reporting period;
3) The date, time and results of each exceedance of the opacity standard;
4) Description of any corrective action taken for each exceedance.
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
U6 Comments
January 1st through March 31th May 30th April 1st through June 30th August 29th
July 1st through September 30th November 29th
October 1st through December 31st March 1st
D.C. Circuit to lift the stay of the Cross State Air Pollution Rule. While the Court considers the motion, CAIR remains in place and no immediate action from States or affected sources is expected.
Emission Unit U7: Sludge processing plant
U7 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
2.04 |
Construction or Modification of Major Sources in or Impacting upon Non-Attainment Areas (Emission Offset Requirements) |
1, 2 |
7.08 |
Standards of Performance for New Affected Facilities |
1, 2, 3, 4, 5, 6 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U7 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
|
North bin silo and associated equipment, |
|
|
|
E9 |
include three flyash separator and one ventilator, make Mikro-Pulsaire, capacity |
|
C11 |
S9 |
|
7 ton/hr |
2.04, 5.00, 5.01, 5.02, |
|
|
E10 |
Unit 4 & 5 SPP flyash silo, make Flex- Kleen, capacity 20 ton/hr |
5.14, 5.20, 5.21, 5.22, 5.23, 7.08 |
C12 |
S10 |
E11 |
Unit 4 &5 SPP lime silo, make Mikro- |
|
C13 |
S11 |
Pulasire, capacity 30 ton/hr |
|
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E12 |
Unit 4 &5 SPP pug mill mixer, make Tri- Mer, capacity 95 ton/hr |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 7.08 |
C14a C14b |
S12 |
E13 |
Unit 6 SPP flyash silo, make Flex-Kleen, capacity 20 ton/hr |
2.04, 5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 7.08 |
C15 |
S13 |
E14 |
Unit 6 SPP lime silo, make Mikro- Pulasire, capacity 30 ton/hr |
C16 |
S14 |
|
E22 |
Unit 6 SPP lime screw conveyor, make Bulk Conveyor Specialists, capacity 2 ton/hr |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 7.08 |
N/A |
N/A |
E23 |
Unit 6 SPP flyash screw conveyor, make Bulk Conveyor Specialists, capacity 40 ton/hr |
N/A |
N/A |
|
E24 |
Unit 6 SPP lime/flyash screw conveyor, make Bulk Conveyor Specialists, capacity 40 ton/hr |
N/A |
N/A |
|
|
Ash conditioner (mixer) A and B, make Bulk Conveyor Specialists, capacity 100 ton/hr for each* |
|
N/A |
N/A |
* The mixers are not listed as emission points due to zero PM emissions |
||||
Note: The owner or operator shall shut down this unit (U7) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U7 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C11 |
Baghouses for north bin silo, make IAC System |
Pressure drop range 0.1” to 12” water column |
S9 |
C12 |
One (1) baghouse (separator) for Unit 4 & 5 SPP flyash silo, make Mikro-Pulsaire |
Pressure drop range 0.1” to 9.0” water column |
S10 |
C13 |
One (1) baghouse (separator)for Unit 4 & 5 SPP lime silo, make Mikro-Pulsaire |
Pressure drop range 0.1” to 6.0” water column |
S11 |
C14a |
One (1) wet cyclone dust collector for Unit 4 & 5 SPP pug mill mixer, make Tri-Mer |
Pressure drop range 0.1” to 8.0” water column |
S12 |
C14b |
One (1) 3-Stage HEPA filter for Unit 4 & 5 SPP pug mill mixer, make Tri-Mer |
Pressure drop range 1” to 4” water column |
ID |
Description |
Performance Indicator |
Stack ID |
C15 |
One (1) baghouse (separator) for Unit 6 SPP flyash silo, make Flex-Kleen |
Pressure drop range 0.1” to 6.0” water column |
S13 |
C16 |
One (1) baghouse (separator) Unit 6 SPP lime silo, make Mikro-Pulsaire |
Pressure drop range 0.1” to 6.0” water column |
S14 |
U7 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
Emission Point |
Description |
Capacity (ton/hr) |
PM Limit* (lb/hr) |
Basis of PM Limit |
E9 |
North bin silo |
27 |
27.7 |
Reg. 7.08, Table 1 |
E10 |
Unit 4 & 5 SPP flyash silo |
20 |
23.0 |
Reg. 7.08, Table 1 |
E11 |
Unit 4 &5 SPP lime silo |
30 |
29.6 |
Reg. 7.08, Table 1 |
E12 |
Unit 4 &5 SPP pug mill mixer |
95 |
35.9 |
Reg. 7.08, Table 1 |
E13 |
Unit 6 SPP flyash silo |
20 |
23.0 |
Reg. 7.08, Table 1 |
E14 |
Unit 6 SPP lime silo |
30 |
29.6 |
Reg. 7.08, Table 1 |
E22 |
Unit 6 SPP lime screw conveyor |
2 |
5.52 |
Reg. 7.08, Table 1 |
E23 |
Unit 6 SPP flyash screw conveyor |
40 |
31.2 |
Reg. 7.08, Table 1 |
E24 |
Unit 6 SPP lime/flyash screw conveyor |
40 |
31.2 |
Reg. 7.08, Table 1 |
* The lb/hr PM limit is based on actual operating hours on a calendar day. |
5.00 and 5.21) (See Comment 4)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 8)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
For E9, E10, E11, E12, E13, and E14:
person conducting the survey, whether or not visible emissions were observed, and what if any corrective action was performed. If an emission point is not being operated during a given month, then no visible emission survey needs to be performed and a negative declaration shall be entered in the record.
|
Date;
Start time and stop time;
Identification of the control device and process equipment; Results of the visible emission survey or Method 9; Summary of the cause or reason for each bypass event;
Corrective action taken to minimize the extent or duration of the bypass event; and
Measures implemented to prevent reoccurrence of the situation that resulted in the bypass event.
owner or operator shall maintain records sufficient to demonstrate environmental acceptability, including, but not limited to MSDS, analysis of emissions, and/or modeling results.
process is operating, then the owner or operator shall keep a record of the following for each bypass event:
1) Date;
2) Start time and stop time;
3) Identification of the control device and process equipment;
4) The hourly throughput rate and total material throughput;
5) The lb/hr and total pounds of Chromium and Arsenic emissions from E9, or Arsenic emissions from E12 during the bypass;
6) Summary of the cause or reason for each bypass event;
7) Corrective action taken to minimize the extent or duration of the bypass event; and
8) Measures implemented to prevent reoccurrence of the situation that resulted in the bypass event.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
For E9, E10, E11, E12, E13, and E14:
1) Number of times the emission points by-pass the baghouses and are vented to the atmosphere;
2) The date, duration (including start and stop time) of each by-pass to the atmosphere;
3) Calculated quantity of tons of PM emitted for each by-pass; and
4) A negative declaration if no by-passes occurred.
1) Any deviation from the requirement to perform daily (or monthly, if required) visible emission surveys or Method 9 tests;
2) Any deviation from the requirement to record the results of each VE survey and Method 9 test performed;
3) The date and time of each VE Survey where visible emissions were observed and the results of any Method 9 test performed;
4) The date, time and results of follow-up VE survey;
5) The date, time, and results of any Method 9 test performed;
6) Identification of all periods of exceeding an opacity standard; and
7) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) Number of times the pug mill mixer by-passes either one or both of the control devices and is vented to the atmosphere;
2) Duration of each by-pass to the atmosphere;
3) Results of the visible emission survey or Method 9; or
4) A negative declaration if no by-passes occurred.
Demonstration do not trigger the requirement to re-analyze. (Regulation 5.21 sections 4.22 – 4.24)
1) Number of times the north bin silo (E9) by-passes C11, or the pug mill mixer (E12) by-passes both C14a and C14b, and is vented to the atmosphere;
2) Duration of each by-pass to the atmosphere;
3) Calculated lbs/hr and total Chromium and Arsenic emissions from E9, or Arsenic emissions from E12 for each by-pass;
4) The re-evaluated EA demonstration if there is an exceedance of de minimis level due to By-Pass activities, or
5) A negative declaration if no by-passes occurred.
U7 Comments
performing environmental acceptability demonstration by modeling, the source is required to demonstrate that the Chromium VI and Arsenic emissions from this equipment are under de minimis level.
Emission Unit U8: Unit 6 SDRS soda ash storage silo
U8 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
2.04 |
Construction or Modification of Major Sources in or Impacting upon Non-Attainment Areas (Emission Offset Requirements) |
1, 2 |
7.08 |
Standards of Performance for New Affected Facilities |
1, 2, 3, 4, 5, 6 |
U8 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E16 |
Unit 6 SDRS soda ash storage silo, make Flex-Kleen, capacity 35 ton/hr |
2.04, 7.08 |
C18 |
S16 |
Note: The owner or operator shall shut down this unit (U8) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U8 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C18 |
One (1) baghouse (separator) for Unit 6 soda ash silo, make Flex-Kleen |
Pressure drop range 0.1” to 4” water column |
S16 |
U8 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not allow visible emissions to equal or exceed 20% opacity. (Regulation 7.08, section 3.1.1)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 4)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
a. |
PM |
|
|
i. |
The owner or operator shall report any deviation from the requirement of performing a monthly visual inspection of the structural and mechanical integrity of the filters. |
|
ii. |
The owner or operator shall identify all periods of the pressure drop across the baghouses exceeding the normal range and any corrective action taken for each exceedance. |
|
iii. |
The owner or operator shall identify any deviation from the requirement to utilize the baghouses at all times the equipment is in operation, including the following: |
|
|
1) Number of times the emission unit by-passes the baghouse and are vented to the atmosphere; 2) The date, duration (including start and stop time) of each by-pass to the atmosphere; 3) Calculated quantity of tons of PM emitted for each by-pass; and 4) A negative declaration if no by-passes occurred. |
The owner or operator shall identify all periods of exceeding an opacity standard during a quarterly reporting period. The report shall include the following:
1) Any deviation from the requirement to perform daily (or monthly, if required) visible emission surveys or Method 9 tests;
2) Any deviation from the requirement to record the results of each VE survey and Method 9 test performed;
3) The date and time of each VE Survey where visible emissions were observed and the results of any Method 9 test performed;
4) The date, time and results of follow-up VE survey;
5) The date, time, and results of any Method 9 test performed;
6) Identification of all periods of exceeding an opacity standard; and
7) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
U8 Comments
Emission Unit U10: Coal handling facilities
U10 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.09 |
Standards of Performance for Existing Process Operations |
1, 2, 3, 4, 5 |
40 CFR 60, Subpart Y |
Standards of Performance for Coal Preparation Plants |
60.250, 60.251, 60.254(a) |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
7.02 |
Federal New Source Performance Standards Incorporated by Reference |
1.1, 1.38, 2, 3, 4, 5 |
U10 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E18 |
One (1) coal radial stacker, rated capacity 1,000 tons/hr (1997) |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 7.02, 7.08 40 CFR 60, Subpart Y |
N/A |
N/A |
E20 |
One (1) coal crusher, rated capacity 1,000 tons/hr (1954/1991) |
N/A |
N/A |
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
|
E21 |
Eighteen (18) coal belt conveyors, rated capacity 1,000 tons/hr for each (1954) |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, |
N/A |
N/A |
|
6.09 |
|||||
E25 |
One (1) railcar unloading hopper, rated |
N/A |
N/A |
||
capacity 1,000 tons/hr (1954) |
|
||||
Note: The owner or operator shall shut down this unit (U10) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. After this unit is shutdown, excess coal will be transferred offsite. The unit will be in operation until excess coal is removed. |
U10 Control Devices:
There is no control device associated with this unit.
U10 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
a. |
PM |
|
|
i. |
The owner or operator shall not allow PM emissions to exceed 52.3 lb/hr, based on actual operating hours on a calendar day, from emission points E18 and E20. (Regulation 7.08, section 3.1.2) (See Comment 1) |
|
ii. |
The owner or operator shall not allow PM emissions to exceed 77.6 lb/hr, based on actual operating hours on a calendar day, from emission points E21 (each belt) and E25. (Regulation 6.09, section 3.2) (See Comment 1) |
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations 5.00 and 5.21) (See Comment 2)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 3)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
The owner or operator shall keep monthly records of the throughput of coal for each emission point.
The owner or operator must determine compliance with the applicable opacity standards as specified in paragraphs (a)(1) through (3) of this section. (40 CFR 60.257(a))
1) Method 9 of appendix A-4 of this part and the procedures in §
60.11 must be used to determine opacity, with the exceptions specified in paragraphs (a)(1)(i) and (ii). (40 CFR 60.257(a)(1))
(a) The duration of the Method 9 of appendix A-4 of this part performance test shall be 1 hour (ten 6-minute averages). (40 CFR 60.257(a)(1)(i))
(b) If, during the initial 30 minutes of the observation of a Method 9 of appendix A-4 of this part performance test, all of the 6- minute average opacity readings are less than or equal to half the applicable opacity limit, then the observation period may be reduced from 1 hour to 30 minutes. (40 CFR 60.257(a)(1)(ii))
2) To determine opacity for fugitive coal dust emissions sources, the additional requirements specified in paragraphs (a)(2)(i) through
(iii) must be used. (40 CFR 60.257(a)(2))
(a) The minimum distance between the observer and the emission source shall be 5.0 meters (16 feet), and the sun shall be oriented in the 140-degree sector of the back. (40 CFR 60.257(a)(2)(i))
(b) The observer shall select a position that minimizes interference from other fugitive coal dust emissions sources and make observations such that the line of vision is approximately perpendicular to the plume and wind direction. (40 CFR 60.257(a)(2)(ii))
(c) The observer shall make opacity observations at the point of greatest opacity in that portion of the plume where condensed water vapor is not present. Water vapor is not considered a visible emission. (40 CFR 60.257(a)(2)(iii))
3) A visible emissions observer may conduct visible emission observations for up to three fugitive, stack, or vent emission points within a 15-second interval if the following conditions specified in paragraphs (a)(3)(i) through (iii) of this section are met. (40 CFR 60.257(a)(3))
(a) No more than three emissions points may be read concurrently. (40 CFR 60.257(a)(3)(i))
(b) All three emissions points must be within a 70 degree viewing sector or angle in front of the observer such that the proper sun position can be maintained for all three points. (40 CFR 60.257(a)(3)(ii))
(c) If an opacity reading for any one of the three emissions points is within 5 percent opacity from the applicable standard (excluding readings of zero opacity), then the observer must stop taking readings for the other two points
and continue reading just that single point. (40 CFR 60.257(a)(3)(iii))
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
There are no routine reporting requirements for this equipment. (See comment 1)
1) Any deviation from the requirement to perform and record the results of visible emission surveys or Method 9 tests;
2) The number, date, and time of each Method 22 where visible emissions were observed and the results of the Method 9 test performed;
3) Identification of all periods of exceeding the opacity standard; and
4) Description of any corrective action taken for each exceedance of the opacity standard.
Protection Agency; Energy Strategies Group; 109 TW Alexander DR; mail code: D243-01; RTP, NC 27711. (40 CFR 60.258(d))
U10 Comments
Emission Unit U11: Gas turbine GT11
U11 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound and Nitrogen Oxides Emitting Facilities |
1, 2, 3, 4, 5, |
40 CFR 63, Subpart ZZZZ |
National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines |
63.6603, 6604, 6605, 6625, 6640, 6645, 6655 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U11 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E7 |
One (1) gas turbine GT11, rated capacity 247 MMBtu/hr, make Westinghouse, model W191G, using natural gas as a primary fuel and #2 fuel oil as secondary fuel, equipped with a 430 HP diesel cranking engine. |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 6.42 40 CFR 63, Subpart ZZZZ |
N/A |
S7 |
U11 Control Devices:
There is no control device associated with this unit.
U11 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations 5.00 and 5.21) (See Comment 2)
1) The owner or operator shall change the oil and filter every 500 hours of operation or annually, whichever comes first. The owner or operator has the option to utilize an oil analysis program as described in 40 CFR 63.6625(i) or (j) in order to extend the specified oil change requirement in Table 2d of this subpart. (40 CFR 63, Subpart ZZZZ, Table 2c.(1)(a) and 2d.(4)(a))
2) The owner or operator shall inspect the air cleaners every 1,000 hours of operation or annually, whichever comes first, and replace as necessary. (40 CFR 63. Subpart ZZZZ, Table 2c.(1)(b) and 2d.(4)(b))
3) The owner or operator shall inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace
as necessary. (40 CFR 63. Subpart ZZZZ, Table 2c.(1)(c) and 2d(4)(c))
1) The owner or operator shall be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to the RICE at all times. (40 CFR 63.6605(a))
2) At all times the owner or operator shall operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. (40 CFR 63.6605(b))
1) Sulfur content: 15 parts per million (ppm) maximum for NR diesel fuel. (40 CFR 80.510(b)(1)(i))
2) A minimum cetane index of 40; or (40 CFR 80.510(b)(2)(i))
3) A maximum aromatic content of 35 volume percent. (40 CFR 80.510(b)(2)(ii))
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
1) The owner or operator shall operate and maintain the stationary RICE and after-treatment control device (if any) according to the manufacturer’s emission-related written instructions or develop your own maintenance plan which shall provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions. (40 CFR 63.6625(e))
2) The owner or operator has the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Tables 2c and 2d to this subpart. The oil analysis shall be performed at the same frequency specified for changing the oil in Table 2c or 2d to this subpart. The analysis program shall at a minimum analyze the following three parameters: Total Base
Number, viscosity, and percent water content. The condemning limits for these parameters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If all of these condemning limits are not exceeded, the engine owner or operator is not required to change the oil. If any of the limits are exceeded, the engine owner or operator shall change the oil within 2 business days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received, the engine owner or operator shall change the oil within 2 business days or before commencing operation, whichever is later. The owner or operator shall keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program shall be part of the maintenance plan for the engine. (40 CFR 63.6625(i))
1) The owner or operator shall keep the following records that apply to your RICE: (40 CFR 63.6655(a))
(a) A copy of each notification and report submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in 40 CFR 63.10(b)(2)(xiv). (40 CFR 63.6655(a)(1))
(b) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (40 CFR 63.6655(a)(2))
(c) Records of performance tests (if stack test is required) and performance evaluations as required in 40 CFR 63.10(b)(2)(viii). (40 CFR 63.6655(a)(3))
(d) Records of all required maintenance performed on the air pollution control and monitoring equipment. (40 CFR 63.6655(a)(4))
(e) Records of actions taken during periods of malfunction to minimize emissions in accordance with 40 CFR 63.6605(b), including corrective actions to restore malfunctioning process and air pollution control and
monitoring equipment to its normal or usual manner of operation. (40 CFR 63.6655(a)(5))
2) The owner or operator shall keep records of the maintenance conducted on the stationary RICE in order to demonstrate that you operated and maintained the stationary RICE and after-treatment control device (if any) according to your own maintenance plan. (40 CFR 63.6655(e))
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
1) Emission Unit ID number, Stack ID number, and/or Emission point ID number,
2) The beginning and ending date of the reporting period,
3) Identification of all periods during which a deviation occurred,
4) A description, including the magnitude, of the deviation,
5) If known, the cause of the deviation, and
6) Description of any corrective action taken for each deviation.
U11 Comments
Emission Unit U14: Porta batch units
U14 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
7.08 |
Standards of Performance for New Affected Facilities |
1, 2, 3 |
U14 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E27 |
One (1) Porta Batch lime slurry mixer (PB1000), make Porta Batch Chemical Lime, capacity 12.5 ton/hr, equipped with an electric motor. |
7.08 |
C19 |
S18 |
E28 |
One (1) Porta Batch lime slurry mixer (PB2000), make Porta Batch Chemical Lime, capacity 12.5 ton/hr, equipped with an electric motor. |
C20 |
S19 |
|
E29 |
One (1) Porta Batch lime slurry mixer (PB3000), make Porta Batch Chemical Lime, capacity 12.5 ton/hr, equipped with an electric motor. |
C21 |
S20 |
|
E30 |
One (1) Porta Batch lime slurry mixer (PB4000), make Porta Batch Chemical Lime, capacity 12.5 ton/hr, equipped with an electric motor. |
C22 |
S21 |
|
Note: The owner or operator shall shut down this unit (U14) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U14 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C19 |
One (1) venturi scrubber for PB1000, make Fisher-Klosterman |
N/A (See Comment 1) |
S18 |
C20 |
One (1) venturi scrubber for PB2000, make Fisher-Klosterman |
N/A (See Comment 1) |
S19 |
C21 |
One (1) venturi scrubber for PB3000, make Fisher-Klosterman |
N/A (See Comment 1) |
S20 |
C22 |
One (1) venturi scrubber for PB4000, make Fisher-Klosterman |
N/A (See Comment 1) |
S21 |
U14 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not allow visible emissions to equal or exceed 20% opacity from Porta batch lime slurry mixers PB1000, PB2000, PB3000, and PB4000 (E27, E28, E29, and E30). (Regulation 7.08, section 3.1.1)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 5)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
There are no routine monitoring and record keeping requirements for this pollutant.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
There are no routine reporting requirements for this pollutant.
The owner or operator shall identify all periods of exceeding an opacity standard during a quarterly reporting period. The report shall include the following:
U14 Comments
4.00 ton/yr in order to avoid the requirements of Regulation 2.05 (PSD).
Emission Unit U15: Natural gas-fired combined cycle (NGCC) unit – EGU 7
U15 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
2.05 |
Prevention of Significant Deterioration of Air Quality |
1, 2 |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound- and Nitrogen Oxides-Emitting Facilities |
1, 2, 3, 4, 5 |
6.47 |
Federal Acid Rain Program for Existing Sources Incorporated by Reference |
1, 2, 3, 4, 5 |
7.09 |
Standards of Performance for New Process Gas Streams |
1, 2, 5 |
40 CFR 60 Subpart KKKK |
Standards of Performance for Stationary Combustion Turbines |
60.4300, 4305, 4310, 4315, 4320, 4325, 4330, 4333, 4340, 4345, 4350, 4360, 4365, 4370, 4375, 4380, 4385, 4390, 4400, 4405, 4410, 4415, 4420 |
40 CFR 72 |
Permits Regulation |
Subparts A, B, C, D, E, F, G, H, I |
40 CFR 73 |
Sulfur Dioxide Allowance System |
Subparts A, B, C, D, E, F, G |
40 CFR 75 |
Continuous Emission Monitoring |
Subparts A, B, C, D, E, F, G |
40 CFR 76 |
Acid Rain Nitrogen Oxides Emission Reduction Program |
76.1, 76.2, 76.3, 76.4, 76.5, 76.7, 76.8, 76.9, 76.11, 76.13, 76.14, 76.15, Appendix A, Appendix B |
40 CFR 77 |
Excess Emissions |
77.1, 77.2, 77.3, 77.4, 77.5, 77.6 |
40 CFR 78 |
Appeals Procedures for Acid Rain Program |
78.1, 78.2, 78.3, 78.4, 78.5, 78.6, 78.8, 78.9, 78.10, 78.11, 78.13, 78.14, 78.15, 78.16, 78.17, 78.18, 78.19, 78.20 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
7.02 |
Federal New Source Performance Standards Incorporated by Reference |
1.1, 1.38, 2, 3, 4, 5 |
U15 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
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One (1) natural gas-fired combustion |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 6.42, 6.47, 7.02, 7.09, 40CFR72-73, 75-78, 40CFR60 Subpart KKKK |
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turbine (F Class), designated as GT-7A, |
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E31 |
make Siemens Energy, model SGT6- |
C23 |
S22 |
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5000F.EE, equipped with a heat recovery |
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steam generator (HRSG)*. |
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One (1) natural gas-fired combustion |
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turbine (F Class), designated as GT-7B, |
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E32 |
make Siemens Energy, model SGT6- |
C24 |
S23 |
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5000F.EE, equipped with a heat recovery |
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steam generator (HRSG)*. |
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* Rated capacity of the NGCC electricity generating unit is 731 MW. |
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Note: This unit (U15) needs to be in full operation no later than November 1, 2015 which is the compliance date for the source to shut down the coal fired boilers and the associated units to comply with 40 CFR 63, Subpart UUUUU. |
U15 Control Devices:
ID |
Description |
Performance Indicator |
Stack ID |
C23 |
One (1) catalytic oxidizer, make Johnson Matthey, model SC42, used to control CO and VOC emissions for turbine GT-7A. |
See Specific Condition S4.b |
S22 |
C24 |
One (1) catalytic oxidizer, make Johnson Matthey, model SC42, used to control CO and VOC emissions for turbine GT-7B. |
See Specific Condition S4.b |
S23 |
U15 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not cause to be discharged into the atmosphere from the subject stationary combustion turbine any gases which contain NOx in excess of 15 ppm at 15% O2 or 54 ng/J of useful output (0.43 lb/MWh), based upon a 30- day rolling average. (40 CFR 60.4320(a)) (Regulation 6.42, section 4.3) (NOx RACT Plan – Amendment 2)
The owner or operator shall comply with either one of the following standards: (40 CFR 60.4330(a))
The owner or operator shall not allow or cause plant-wide VOC emissions to exceed 97.0 tons in a 12 consecutive month period. (Regulation 2.05) (See Comment 2)
Effective from November 1, 2015, the owner or operator shall not allow or cause HAP emissions from this plant to exceed 10 tons for a single HAP or 25 tons for total HAPs in a 12 consecutive month period. (Regulation 2.16, section 4.1.1) (See Comment 3)
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations 5.00 and 5.21) (See Comment 4)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 8)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
1) The owner or operator must operate and maintain the stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown, and malfunction. (60.4333(a))
2) When an affected unit with heat recovery utilizes a common steam header with one or more combustion turbines, the owner or operator shall either: (60.4333(b))
(a) Determine compliance with the applicable NOX emissions limits by measuring the emissions combined with the emissions from the other unit(s) utilizing the common heat recovery unit; or (60.4333(b)(1))
(b) Develop, demonstrate, and provide information satisfactory to the Administrator (EPA or the District) on methods for apportioning the combined gross energy output from the heat recovery unit for each of the affected combustion turbines. The Administrator may approve such demonstrated substitute methods for apportioning the combined gross energy output measured at the steam turbine whenever the demonstration ensures accurate estimation of emissions related under this part. (60.4333(b)(2))
1) Install, certify, maintain, and operate a continuous emission monitoring system (CEMS) consisting of a NOX monitor and a diluent gas (oxygen (O2) or carbon dioxide (CO2)) monitor, to determine the hourly NOx emission rate in parts per million (ppm) or pounds per million British thermal units (lb/MMBtu); (40 CFR 60.4335(b)(1))
2) For units complying with the output-based standard, install, calibrate, maintain, and operate a fuel flow meter (or flow meters) to continuously measure the heat input to the affected unit; (40 CFR 60.4335(b)(2))
3) For units complying with the output-based standard, install, calibrate, maintain, and operate a watt meter (or meters) to continuously measure the gross electrical output of the unit in megawatt-hours; and (40 CFR 60.4335(b)(3))
– Amendment 2)
1) Each NOx diluent CEMS must be installed and certified according to Performance Specification 2 (PS 2) in appendix B to this part, except the 7-day calibration drift is based on unit operating days,
not calendar days. With state approval, Procedure 1 in appendix F to this part is not required. Alternatively, a NOX diluent CEMS that is installed and certified according to appendix A of part 75 of this chapter is acceptable for use under this subpart. The relative accuracy test audit (RATA) of the CEMS shall be performed on a lb/MMBtu basis. (40 CFR 60.4345(a))
2) As specified in § 60.13(e)(2), during each full unit operating hour, both the NOX monitor and the diluent monitor must complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each 15-minute quadrant of the hour, to validate the hour. For partial unit operating hours, at least one valid data point must be obtained with each monitor for each quadrant of the hour in which the unit operates. For unit operating hours in which required quality assurance and maintenance activities are performed on the CEMS, a minimum of two valid data points (one in each of two quadrants) are required for each monitor to validate the NOX emission rate for the hour. (40 CFR 60.4345(b))
3) Each fuel flowmeter shall be installed, calibrated, maintained, and operated according to the manufacturer’s instructions. Alternatively, with state approval, fuel flowmeters that meet the installation, certification, and quality assurance requirements of appendix D to part 75 of this chapter are acceptable for use under this subpart. (40 CFR 60.4345(c))
4) Each watt meter, steam flow meter, and each pressure or temperature measurement device shall be installed, calibrated, maintained, and operated according to manufacturer’s instructions. (40 CFR 60.4345(d))
5) The owner or operator shall develop and keep on-site a quality assurance (QA) plan for all of the continuous monitoring equipment described in paragraphs (a), (c), and (d) of this section. For the CEMS and fuel flow meters, the owner or operator may, with state approval, satisfy the requirements of this paragraph by implementing the QA program and plan described in section 1 of appendix B to part 75 of this chapter. (40 CFR 60.4345(e))
1) All CEMS data must be reduced to hourly averages as specified in
§60.13(h). (40 CFR §60.4350(a))
2) For each unit operating hour in which a valid hourly average, as described in §60.4345(b), is obtained for both NOX and diluent monitors, the data acquisition and handling system must calculate and record the hourly NOX emission rate in units of ppm or lb/MMBtu, using the appropriate equation from Method 19 in appendix A of this part. For any hour in which the hourly average O2 concentration exceeds 19.0 percent O2 (or the hourly average CO2 concentration is less than 1.0 percent CO2), a diluent cap value of 19.0 percent O2 or 1.0 percent CO2 (as applicable) may be used in the emission calculations. (40 CFR §60.4350(b))
3) Correction of measured NOX concentrations to 15 percent O2 is not allowed. (40 CFR §60.4350(c))
4) If the owner or operator have installed and certified a NOX diluent CEMS to meet the requirements of part 75 of this chapter, states can approve that only quality assured data from the CEMS shall be used to identify excess emissions under this subpart. Periods where the missing data substitution procedures in subpart D of part 75 are applied are to be reported as monitor downtime in the excess emissions and monitoring performance report required under
§60.7(c). (40 CFR §60.4350(d))
5) All required fuel flow rate, steam flow rate, temperature, pressure, and megawatt data must be reduced to hourly averages. (40 CFR
§60.4350(e))
6) Calculate the hourly average NOX emission rates, in units of the emission standards under §60.4320, using either ppm for units complying with the concentration limit or the following equation for units complying with the output based standard: (40 CFR
§60.4350(f))
(a) For combined-cycle and combined heat and power complying with the output-based standard, use Equation 1 of this subpart, except that the gross energy output is calculated as the sum of the total electrical and mechanical energy generated by the combustion turbine, the additional electrical or mechanical energy (if any) generated by the steam turbine following the heat recovery steam generator, and 100 percent of the total useful thermal energy output that is not used to generate additional electricity or mechanical output, expressed in equivalent MW, as in the following equations: (40 CFR §60.4350(f)(2))
(Eq. 1)
Where:
E = hourly NOx emission rate, in lb/MWh (NOx)h = hourly NOx emission rate, in lb/MMBtu
(HI)h = hourly heat input rate to the unit, in MMBtu/hr, measured using the fuel flowmeters, e.g., calculated using Equation D-15a in appendix D to part 75 of this chapter, and
P = gross energy output of the combustion turbine in MW
(Eq. 2)
Where:
P = gross energy output of the stationary combustion turbine system (MW)
(PE)t = electrical or mechanical energy output of the CT (MW)
(PE)c = electrical or mechanical output of the steam turbine (MW)
(Eq. 3)
Where:
Ps = useful thermal energy of the system, measured relative to ISO conditions, not used to generate additional electric or mechanical output, in MW
Q = measured steam flow rate in lb/hr
H = enthalpy of steam at measured temperature and pressure relative to ISO conditions, in Btu/lb, and
3.413 x 106 = conversion from Btu/hr to MW
Po = other useful heat recovery, measured relative to ISO conditions, not used for steam generation or performance enhancement of the combustion turbine.
7) For combined cycle and combined heat and power units with heat recovery, use the calculated hourly average emission rates from paragraph (f) of this section to assess excess emissions on a 30 unit operating day rolling average basis, as described in
§60.4380(b)(1). (40 CFR 60.4350(h))
specified in the effective rules. (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2) (See Comment 9)
1) The fuel quality characteristics in a current, valid purchase contract, tariff sheet or transportation contract for the fuel, specifying that the maximum total sulfur content for oil use in continental areas is 0.05 weight percent (500 ppmw) or less and
0.4 weight percent (4,000 ppmw) or less for non-continental areas, the total sulfur content for natural gas use in continental areas is 20 grains of sulfur or less per 100 standard cubic feet and 140 grains of sulfur or less per 100 standard cubic feet for non-continental areas, has potential sulfur emissions of less than less than 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input for continental areas and has potential sulfur emissions of less than less than 180 ng SO2/J (0.42 lb SO2/MMBtu) heat input for non-continental areas; or (40 CFR 60.4365(a))
2) Representative fuel sampling data which show that the sulfur content of the fuel does not exceed 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input for continental areas or 180 ng SO2/J (0.42 lb SO2/MMBtu) heat input for non-continental areas. At a minimum, the amount of fuel sampling data specified in section
2.3.1.4 or 2.3.2.4 of appendix D to part 75 of this chapter is required. (40 CFR 60.4365(b))
1) Before beginning actual construction of the project, the owner or operator shall document and maintain a record of the following information: (40 CFR 52.21(r)(6)(i))
(a) A description of the project; (40 CFR 52.21(r)(6)(i)(a))
(b) Identification of the emissions unit(s) whose emissions of a regulated NSR pollutant could be affected by the project; and (40 CFR 52.21(r)(6)(i)(b))
(c) A description of the applicability test used to determine that the project is not a major modification for any regulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the amount of emissions excluded under 40 CFR 52.21(b)(41)(ii)(c) and an explanation for why such amount was excluded, and any netting calculations, if applicable. (40 CFR 52.21(r)(6)(i)(c))
2) The owner or operator shall provide a copy of the information set out in 40 CFR 52.21(r)(6)(i) to the Administrator. Nothing in this paragraph (r)(6)(ii) shall be construed to require the owner or
operator of such a unit to obtain any determination from the Administrator before beginning actual construction. (40 CFR 52(r)(6)(ii))
3) The owner or operator shall monitor the emissions of any regulated NSR pollutant that could increase as a result of the project and that is emitted by any emissions unit identified in 40 CFR 52.21(r)(6)(i)(b), and calculate and maintain a record of the annual emissions, in tons per year on a calendar year basis, for a period of
5 years following resumption of regular operations after the change. (40 CFR 52(r)(6)(iii))
The owner or operator shall monthly calculate and record the plant-wide emissions for Formaldehyde, and subsequently calculate the total emissions for Formaldehyde during the 12 consecutive month period in order to demonstrate compliance with Specific Condition S1.e.
The owner or operator shall record the date when the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous
U12), and U14 shut down, and record the date when the new emission unit U15, U16, and U18 become operational and begin to emit a particular pollutant. (See Comment 8)
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
1) The magnitude of excess emissions computed in accordance with § 60.13(h), any conversion factor(s) used, and the date and time of commencement and completion of each time period of excess emissions. The process operating time during the reporting period. (40 CFR 60.7(c)(1))
2) Specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the affected facility. The nature and cause of any malfunction (if known), the corrective action taken or preventative measures adopted. (40 CFR 60.7(c)(2))
3) The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and
span checks and the nature of the system repairs or adjustments. (40 CFR 60.7(c)(3))
4) When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report. (40 CFR 60.7(c)(4))
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
1) An excess emissions is any unit operating period in which the 4- hour or 30-day rolling average NOX emission rate exceeds the applicable emission limit in § 60.4320. For the purposes of this subpart, a “4-hour rolling average NOX emission rate” is the arithmetic average of the average NOX emission rate in ppm or ng/J (lb/MWh) measured by the continuous emission monitoring equipment for a given hour and the three unit operating hour average NOX emission rates immediately preceding that unit operating hour. Calculate the rolling average if a valid NOX emission rate is obtained for at least 3 of the 4 hours. For the purposes of this subpart, a “30-day rolling average NOX emission rate” is the arithmetic average of all hourly NOX emission data in ppm or ng/J (lb/MWh) measured by the continuous emission monitoring equipment for a given day and the twenty-nine unit operating days immediately preceding that unit operating day. A new 30-day average is calculated each unit operating day as the
average of all hourly NOX emissions rates for the preceding 30 unit operating days if a valid NOX emission rate is obtained for at least 75 percent of all operating hours. (40 CFR 60.4380(b)(1))
2) A period of monitor downtime is any unit operating hour in which the data for any of the following parameters are either missing or invalid: NOX concentration, CO2 or O2 concentration, fuel flow rate, steam flow rate, steam temperature, steam pressure, or megawatts. The steam flow rate, steam temperature, and steam pressure are only required if the owner or operator will use this information for compliance purposes. (40 CFR 60.4380(b)(2))
The owner or operator shall identify all periods of exceeding a SO2 emission standard during a quarterly reporting period. The quarterly compliance report shall include the following:
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1) Emission Unit ID number and emission point ID number; 2) Identification of all periods during which a deviation occurred; 3) A description, including the magnitude, of the deviation; 4) If known, the cause of the deviation; 5) A description of all corrective actions taken to abate the deviation; and 6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration. |
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d. |
CO |
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i. |
The owner or operator shall submit a report to the Administrator within 60 days after the end of each year during which records must be generated under 40 CFR 52.21(r)(6)(iii) setting out the unit’s annual emissions during the calendar year that preceded submission of the report. (40 CFR 52.21(r)(6)(iv)) |
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ii. |
The owner or operator shall identify all periods of plant-wide total CO emissions exceeding the standard during a quarterly reporting period. The quarterly compliance report shall include the following: |
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1) Identification of all periods during which a deviation occurred; 2) A description, including the magnitude, of the deviation; 3) If known, the cause of the deviation; 4) A description of all corrective actions taken to abate the deviation; and 5) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration. |
1) Identification of all periods during which a deviation occurred;
2) A description, including the magnitude, of the deviation;
3) If known, the cause of the deviation;
4) A description of all corrective actions taken to abate the deviation; and
5) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
The owner or operator shall identify all periods of plant-wide total Formaldehyde emissions exceeding the major source threshold for single HAP during a quarterly reporting period. The quarterly compliance report shall include the following:
The owner or operator shall submit a report to the Administrator within 30 days after the new emission units become operational and begins to emit a particular pollutant, which include the date when the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 shut down, and the date when the new emission unit U15, U16, and U18 become operational and begins to emit a particular pollutant. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 8)
S4. Testing (Regulation 2.16, section 4.1.9.1)
Unless otherwise required by any other applicable regulations, the following testing requirements apply to performance tests required by this permit:
1) Perform a minimum of nine RATA reference method runs, with a minimum time per run of 21 minutes, at a single load level, within plus or minus 25 percent of 100 percent of peak load. The ambient temperature must be greater than 0 ° F during the RATA runs. (40 CFR 60.4405(a))
2) For each RATA run, concurrently measure the heat input to the unit using a fuel flow meter (or flow meters) and measure the electrical and thermal output from the unit. (40 CFR 60.4405(b))
3) Use the test data both to demonstrate compliance with the applicable NOX emission limit under § 60.4320 and to provide the required reference method data for the RATA of the CEMS described under § 60.4335. (40 CFR 60.4405(c))
4) Compliance with the applicable emission limit in § 60.4320 is achieved if the arithmetic average of all of the NOX emission rates for the RATA runs, expressed in units of ppm or lb/MWh, does not exceed the emission limit. (40 CFR 60.4405(d))
1) If the stationary combustion turbine combusts both oil and gas as primary or backup fuels, separate performance testing is required for each fuel. (40 CFR 60.4400(b)(1))
2) If water or steam injection is used to control NOX with no additional post-combustion NOX control and the owner or operator choose to monitor the steam or water to fuel ratio in accordance with § 60.4335, then that monitoring system must be operated concurrently with each EPA Method 20 or EPA Method 7E run and must be used to determine the fuel consumption and the steam or water to fuel ratio necessary to comply with the applicable § 60.4320 NOX emission limit. (40 CFR 60.4400(b)(3))
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3) Compliance with the applicable emission limit in § 60.4320 must be demonstrated at each tested load level. Compliance is achieved if the three-run arithmetic average NOX emission rate at each tested level meets the applicable emission limit in § 60.4320. (40 |
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CFR 60.4400(b)(4)) |
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4) If the owner or operator elects to install a CEMS, the performance |
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evaluation of the CEMS may either be conducted separately or (as |
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described in § 60.4405) as part of the initial performance test of the |
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affected unit. (40 CFR 60.4400(b)(5)) |
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5) The ambient temperature must be greater than 0 °F during the |
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performance test. (40 CFR 60.4400(b)(6)) |
60.8. Subsequent SO2 performance tests shall be conducted on an annual basis (no more than 14 calendar months following the previous performance test). There are three methodologies that the owner or operator may use to conduct the performance tests. (40 CFR 60.4415(a))
1) If the owner or operator chooses to periodically determine the sulfur content of the fuel combusted in the turbine, a representative fuel sample would be collected following ASTM D5287 (incorporated by reference, see § 60.17) for natural gas or ASTM D4177 (incorporated by reference, see § 60.17) for oil. Alternatively, for oil, the owner or operator may follow the procedures for manual pipeline sampling in section 14 of ASTM D4057 (incorporated by reference, see § 60.17). The fuel analyses of this section may be performed either by the owner or operator, a service contractor retained by the owner or operator, the fuel vendor, or any other qualified agency. Analyze the samples for the total sulfur content of the fuel using: (40 CFR 60.4415(a)(1))
(a) For liquid fuels, ASTM D129, or alternatively D1266, D1552, D2622, D4294, or D5453 (all of which are incorporated by reference, see § 60.17); or (40 CFR 60.4415(a)(1)(i))
(b) For gaseous fuels, ASTM D1072, or alternatively D3246, D4084, D4468, D4810, D6228, D6667, or Gas Processors Association Standard 2377 (all of which are incorporated by reference, see § 60.17). (40 CFR 60.4415(a)(1)(ii))
2) Measure the SO2 concentration (in parts per million (ppm)), using EPA Methods 6, 6C, 8, or 20 in appendix A of this part. In addition, the American Society of Mechanical Engineers (ASME) standard, ASME PTC 19–10–1981–Part 10, “Flue and Exhaust Gas Analyses,” manual methods for sulfur dioxide (incorporated by reference, see § 60.17) can be used instead of EPA Methods 6 or 20. For units complying with the output based standard, concurrently measure the stack gas flow rate, using EPA Methods 1 and 2 in appendix A of this part, and measure and record the electrical and thermal output from the unit. Then use the following equation to calculate the SO2 emission rate: (40 CFR 60.4415(a)(2))
(Eq.6)
Where:
E = SO2 emission rate, in lb/MWh
1.664 x 10 -7= conversion constant, in lb/dscf-ppm (SO2)c= average SO2 concentration for the run, in ppm Qstd= stack gas volumetric flow rate, in dscf/hr
P = gross electrical and mechanical energy output of the combustion turbine, in MW (for simple-cycle operation), for combined-cycle operation, the sum of all electrical and mechanical output from the combustion and steam turbines, or, for combined heat and power operation, the sum of all electrical and mechanical output from the combustion and steam turbines plus all useful recovered thermal output not used for additional electric or mechanical generation, in MW, calculated according to § 60.4350(f)(2); or
3) Measure the SO2 and diluent gas concentrations, using either EPA Methods 6, 6C, or 8 and 3A, or 20 in appendix A of this part. In addition, the owner or operator may use the manual methods for sulfur dioxide ASME PTC 19–10–1981–Part 10 (incorporated by reference, see § 60.17). Concurrently measure the heat input to the unit, using a fuel flowmeter (or flowmeters), and measure the electrical and thermal output of the unit. Use EPA Method 19 in appendix A of this part to calculate the SO2 emission rate in lb/MMBtu. Then, use Equations 1 and, if necessary, 2 and 3 in §
60.4350(f) to calculate the SO2 emission rate in lb/MWh. (40 CFR 60.4415(a)(3))
The owner or operator shall perform an EPA Reference Method 25A performance test within 180 days of becoming operational and begins to emit a particular pollutant, and then test every 10 years thereafter based on the date of the previous stack test, in order to determine emission rate for VOC.
The owner or operator shall perform a performance test within 180 days of becoming operational and begins to emit a particular pollutant, and then test every
10 years thereafter based on the date of the previous stack test, in order to determine emission rate for Formaldehyde, using EPA Reference Method 320 or 323, ARB Method 430, SW-846 Method 0011, or other test methods for Formaldehyde approved by the District.
U15 Comments
57.0 tons) and the PSD/NSR significant emission rate (CO = 100 tons; VOC = 40 tons). The 12 consecutive month rolling emissions include the annual emissions required by 40 CFR 52.21(r)(6)(iii).
D.C. Circuit to lift the stay of the Cross State Air Pollution Rule. While the Court considers the motion, CAIR remains in place and no immediate action from States or affected sources is expected.
Emission Unit U16: Natural gas-fired auxiliary boiler
U16 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
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Regulation |
Title |
Applicable Sections |
2.05 |
Prevention of Significant Deterioration of Air Quality |
1, 2 |
6.42 |
Reasonably Available Control Technology Requirements for Major Volatile Organic Compound- and Nitrogen Oxides-Emitting Facilities |
1, 2, 3, 4, 5 |
7.06 |
Standards of Performance for New Indirect Heat Exchangers |
1 through 8 |
40 CFR 60 Subpart DC |
Standards of Performance for Small Industrial- Commercial-Institutional Steam Generating Units |
60.40c, 60.41c, 60.42c, 60.43c, 60.44c, 60.45c, 60.46c, 60.47c, 60.48c |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
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Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
7.02 |
Federal New Source Performance Standards Incorporated by Reference |
1.1, 1.38, 2, 3, 4, 5 |
U16 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
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One (1) natural gas-fired auxiliary boiler |
5.00, 5.01, 5.02, 5.14, |
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E33 |
with low NOx burners, make Cleaver Brooks, model CP-NB-200D-45-250, |
5.20, 5.21, 5.22, 5.23, 6.42, 7.02, 7.06, |
N/A |
S24 |
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capacity 59.9 MMBtu/hr. |
40CFR60 Subpart Dc |
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Note: This unit (U16) needs to be in full operation no later than November 1, 2015 which is the compliance date for the source to shut down the coal fired boilers and the associated units to comply with 40 CFR 63, Subpart UUUUU. |
U16 Control Devices:
There are no control devices associated with this unit.
U16 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not cause to be discharged into the atmosphere from this unit NOx emissions in excess of 3.60 lb/hr based upon a rolling 30-day average. (NOx RACT Plan) (Regulation 6.42, section 4.3)
The owner or operator shall not cause to be discharged into the atmosphere from each affected facility any gases which contain SO2 in excess of 1.0 lb/MMBtu actual total heat input based upon a rolling 30-day average. (Regulation 7.06, section 5.1.1) (See Comment 3)
The owner or operator shall not cause to be discharged into the atmosphere from each affected facility PM in excess of 0.154 lb/MMBtu actual total heat input based upon a rolling 30-day average. (Regulation 7.06, section 4.1.4) (See Comment 3)
The owner or operator combusting natural gas shall not cause to be discharged into the atmosphere from any affected facility PM emissions which exhibit greater than 20% opacity. (Regulation 7.06, section 4.2) (See Comment 4)
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations 5.00 and 5.21) (See Comment 5)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
The owner or operator shall record and maintain records of the amount of fuel combusted in each unit during each calendar month. (40 CFR 60.48c(g)(2)) (See Comment 3)
There are no routine monitoring or record keeping requirements for this pollutant. (See Comment 3)
There are no monitoring and record keeping requirements for this pollutant. (See Comment 4)
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
The owner or operator shall submit notification of the date of construction or reconstruction and actual startup, as provided by 40 CFR 60.7. The notification shall include the design heat input capacity of the affected facility and identification of fuels to be combusted in the affected facility. (40 CFR 60.48c(a))
The owner or operator shall identify all periods of exceeding a NOx emission standard during a quarterly reporting period. The quarterly compliance report shall include the following:
1) Emission Unit ID number and emission point ID number;
2) Identification of all periods during which a deviation occurred;
3) A description, including the magnitude, of the deviation;
4) If known, the cause of the deviation;
5) A description of all corrective actions taken to abate the deviation; and
6) If no deviations occur during a quarterly reporting period, the report shall contain a negative declaration.
There are no routine reporting requirements for this pollutant. (See Comment 3)
There are no routine reporting requirements for this pollutant. (See Comment 3)
There are no routine reporting requirements for this pollutant. (See Comment 4)
Demonstration do not trigger the requirement to re-analyze. (Regulation 5.21 sections 4.22 – 4.24)
U16 Comments
Emission Unit U18: Emergency generator
U18 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
40 CFR 63, Subpart ZZZZ |
National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines |
63.6603, 6604, 6605, 6625, 6640, 6645, 6655 |
40 CFR 60, Subpart IIII |
Standards of Performance for Stationary Compression Ignition Internal Combustion Engines |
60.4200 – 4219 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
7.02 |
Federal New Source Performance Standards Incorporated by Reference |
1.1, 1.38, 2, 3, 4, 5 |
U18 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E35 |
One (1) Emergency diesel generator, make Caterpillar, model C27, maximum output 1,006 hp (750 KW), equipped with a 660 gallons storage tank. Model year 2014. |
5.00, 5.01, 5.02, 5.14, 5.20, 5.21, 5.22, 5.23, 40CFR60 Subpart IIII, 40CFR63 Subpart ZZZZ |
N/A |
S26 |
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
Note: This unit (U18) needs to be in full operation no later than November 1, 2015 which is the compliance date for the source to shut down the coal fired boilers and the associated units to comply with 40 CFR 63, Subpart UUUUU. |
U18 Control Devices:
There are no control devices associated with this unit.
U18 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
1) Operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer’s emission- related written instructions; (40 CFR 60.4211(a)(1))
2) Change only those emission-related settings that are permitted by the manufacturer; (40 CFR 60.4211(a)(2))
Engine manufacturers shall certify the engines with the exhaust emission standards in the following table. In lieu of the NOX standards, NMHC + NOX standards, and PM standards, manufacturers may elect to include engine families in the averaging, banking, and trading program. The manufacturer must set a family emission limit (FEL) not to exceed the levels contained in the following table: (40 CFR 89.112)
unit: g/KW-hr |
NOx |
HC |
NMHC+ NOx |
CO |
PM |
Emission Standards |
N/A |
N/A |
6.4 |
3.5 |
0.2 |
Family Emission Limits |
N/A |
N/A |
10.5 |
N/A |
0.54 |
1) There is no time limit on the use of emergency stationary ICE in emergency situations. (40 CFR 60.4211(f)(1))
2) The owner or operator may operate the emergency stationary ICE for any combination of the purposes specified in 60 CFR 60.4211(f)(2)(i) through (iii) for a maximum of 100 hours per calendar year. Any operation for non-emergency situations as allowed by 60 CFR 60.4211(f)(3) counts as part of the 100 hours per calendar year allowed by this paragraph. (40 CFR 60.4211(f)(2)).
(a) Emergency stationary ICE may be operated for maintenance checks and readiness testing, provided that the tests are recommended by federal, state or local government, the manufacturer, the vendor, the regional transmission organization or equivalent balancing authority and transmission operator, or the insurance company associated with the engine. The owner or operator may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that federal, state, or local standards require maintenance and testing of emergency ICE beyond 100 hours per calendar year. (40 CFR 60.4211(f)(2)(i))
(b) Emergency stationary ICE may be operated for emergency demand response for periods in which the Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP-002-3, Capacity and Energy Emergencies (incorporated by reference, see 40 CFR 60.17), or other authorized entity as determined by the Reliability Coordinator, has declared an Energy Emergency Alert Level 2 as defined in the NERC Reliability Standard EOP-002-3. (40 CFR 60.4211(f)(2)(ii))
(c) Emergency stationary ICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency. (40 CFR 60.4211(f)(2)(iii))
3) Emergency stationary ICE may be operated for up to 50 hours per calendar year in non-emergency situations. The 50 hours of operation in non-emergency situations are counted as part of the
100 hours per calendar year for maintenance and testing and emergency demand response provided in 40 CFR 60.4211(f)(2). Except as provided in 40 CFR 60.4211(f)(3)(i), the 50 hours per
calendar year for non-emergency situations cannot be used for peak shaving or non-emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity. (40 CFR 60.4211(f)(3))
(a) The 50 hours per year for non-emergency situations can be used to supply power as part of a financial arrangement with another entity if all of the following conditions are met: (40 CFR 60.4211(f)(3)(i))
(i) The engine is dispatched by the local balancing authority or local transmission and distribution system operator; (40 CFR 60.4211(f)(3)(i)(A))
(ii) The dispatch is intended to mitigate local transmission and/or distribution limitations so as to avert potential voltage collapse or line overloads that could lead to the interruption of power supply in a local area or region. (40 CFR 60.4211(f)(3)(i)(B))
(iii) The dispatch follows reliability, emergency operation or similar protocols that follow specific NERC, regional, state, public utility commission or local standards or guidelines. (40 CFR 60.4211(f)(3)(i)(C))
(iv) The power is provided only to the facility itself or to support the local transmission and distribution system. (40 CFR 60.4211(f)(3)(i)(D))
(v) The owner or operator identifies and records the entity that dispatches the engine and the specific NERC, regional, state, public utility commission or local standards or guidelines that are being followed for dispatching the engine. The local balancing authority or local transmission and distribution system operator may keep these records on behalf of the engine owner or operator. (40 CFR 60.4211(f)(3)(i)(E))
The owner or operator shall not combust in the engine a non-road diesel fuel that contains more than 15 ppm of sulfur. (40 CFR 60.4207(b)) (40 CFR 80.510(b)(1)(i))
The equipment listed in this emission unit is subject to 40 CFR 63, Subpart ZZZZ, however, there are no HAP standards. (See Comment 1)
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations 5.00 and 5.21) (See Comment 3)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
The owner or operator shall maintain records of the fuel MSDS sheets and receipts showing dates, amounts of fuel purchased, sulfur content of fuel purchased and supplier’s name and address, to show compliance with Specific Condition S1.b.
There are no compliance monitoring or record keeping requirements for HAP. (See Comment 1)
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
a. Unit Operation
The owner or operator shall identify all periods of exceeding the hour limits specified in Specific Condition S1.a.ix during the reporting period. The compliance report shall include the following:
|
i. |
Identification of all periods during which a deviation occurred; |
ii. |
A description, including the magnitude, of the deviation; |
|
iii. |
If known, the cause of the deviation; |
|
iv. |
A description of all corrective actions taken to abate the deviation; and |
|
v. |
If no deviations occur during a reporting period, the report shall contain a |
|
b. |
SO2 |
negative declaration. |
There are no routine compliance reporting requirements for this equipment.
There are no routine compliance reporting requirements for this equipment. (See Comment 1)
U18 Comments
Emission Unit U19: Haul Roads
U19 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
1.14 |
Control of Fugitive Particulate Emissions |
1, 2, 3, 4, 8, 9 |
U15 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E36a |
Paved road particulate emissions |
1.14 |
N/A |
N/A |
E37b |
Unpaved road particulate emissions |
1.14 |
N/A |
N/A |
U19 Control Devices:
Particulate emissions from unpaved road are controlled according to the plant-wide Fugitive Dust Control Plan (See Attachment C).
U19 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not allow a road to be used without taking reasonable precautions to prevent particulate matter from becoming airborne beyond the work site. Such precautions shall include, where applicable, but shall not be limited to the following: (Regulation 1.14, section 2.1)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
The owner or operator shall keep records of vehicle miles traveled (VMT) and weights for the vehicles traveled on unpaved and paved roads.
See Specific Condition S2.a.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
PM/ Opacity
The owner or operator shall report any deviation from the attached Fugitive Dust Control Plan during the reporting period.
U19 Comments
Emission Unit U20: Landfill
U20 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
1.14 |
Control of Fugitive Particulate Emissions |
1, 2, 3, 4, 5, 8, 9 |
DISTRICT ONLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
5.00 |
Definitions |
1, 2 |
5.01 |
General Provisions |
1 through 2 |
5.02 |
Adoption of National Emission Standards for Hazardous Air Pollutants |
1, 3.95 and 4 |
5.14 |
Hazardous Air Pollutants and Source Categories |
1, 2 |
5.20 |
Methodology for Determining Benchmark Ambient Concentration of a Toxic Air Contaminant |
1 through 6 |
5.21 |
Environmental Acceptability for Toxic Air Contaminants |
1 through 5 |
5.22 |
Procedures for Determining the Maximum Ambient Concentration of a Toxic Air Contaminant |
1 through 5 |
5.23 |
Categories of Toxic Air Contaminants |
1 through 6 |
U20 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E37a |
Landfill haul roads |
1.14 |
|
|
E37b |
Landfill drop points |
1.14 |
|
|
E37c |
Landfill wind erosion emissions |
1.14 |
|
|
Note: The owner or operator shall shut down this unit (U20) prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. |
U20 Control Devices:
Particulate emissions from landfill haul roads are controlled according to the plant-wide Fugitive Dust Control Plan (See Attachment C).
U20 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
The owner or operator shall not allow any materials to be handled, transported, or stored, or a road to be used without taking reasonable precautions to prevent particulate matter from becoming airborne beyond the work site. Such precautions shall include, where applicable, but shall not be limited to the following: (Regulation 1.14, section 2.1)
The owner or operator shall not allow emissions of any TAC to exceed environmentally acceptable (EA) levels, whether specifically established by modeling or determined by the District to be de minimis. (Regulations
5.00 and 5.21) (See Comment 2)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
See Specific Condition S2.a.
c. |
TAC |
|
|
i. |
The owner or operator shall maintain records sufficient to demonstrate environmental acceptability, including, but not limited to MSDS, analysis of emissions, and/or modeling results. |
|
ii. |
If a new TAC is introduced or the content of a TAC in a raw material increases, the owner or operator shall re-evaluate the environmental acceptability and document the environmentally acceptable emissions. |
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
a. PM/ Opacity
The owner or operator shall report any deviation from the attached Fugitive Dust Control Plan during the reporting period.
b. |
TAC |
|
|
i. |
The owner or operator shall report any conditions that were inconsistent with those conditions analyzed in the most recent Environmental Acceptability Demonstration or a negative declaration stating that operations were within the conditions analyzed. This includes, but is not limited to, control device upset conditions. |
|
ii. |
For any conditions outside the analysis, the owner or operator shall re- analyze to determine whether these conditions comply with the STAR program. Changes to the air dispersion modeling program or meteorological data used in the most recent Environmental Acceptability |
Demonstration do not trigger the requirement to re-analyze. (Regulation 5.21 sections 4.22 – 4.24)
U20 Comments
Permit Shield
The owner or operator is hereby granted a permit shield that shall apply as long as the owner or operator demonstrates ongoing compliance with all conditions of this permit. Compliance with the conditions of this permit shall be deemed compliance with all applicable requirements of the regulations cited in this permit as of the date of issuance, pursuant to Regulation 2.16, section 4.6.1.
Off-Permit Documents
There are no off-permit documents associated with this Title V permit.
Alternative Operating Scenario
The company requested no alternative operating scenario in its Title V application.
Insignificant Activities
Insignificant activities prior to NGCC construction project
Equipment |
Quan. |
PTE (tpy) |
Regulation Basis |
Indirect heat exchangers <10 MMBtu/hr |
16 |
0.74 SO2 |
Regulation 1.02, Appendix A |
Gasoline storage tank, 560 gallons (previous U9, see unit IA1) |
1 |
0.19 VOC |
Regulation 2.16, section 1.23 |
Cold solvent parts washers with secondary reservoir (previous U12, see unit IA2) |
5 |
0.33 VOC |
Regulation 1.02, Appendix A |
Coal pile |
1 |
2.56 PM10 |
Regulation 2.16, section 1.23 |
Emergency generators (See unit IA-EG) |
N/A |
N/A |
Regulation 2.16, section 1.23 |
Note: Twelve (12) fuel or lubricating oils storage tanks, fifty one (51) emergency relief vents for boiler steam supply, three (3) lab exhaust systems, one (1) ash pond with wet storage, six (6) diesel storage tanks, and two (2) portable fuel storage tanks (< 500 gal) are delisted from the insignificant activities due to their trivial emissions (< 0.01 tpy) under normal operation. |
Insignificant activities after NGCC construction project
Equipment |
Quan. |
PTE (tpy) |
Regulation Basis |
Indirect heat exchangers <10 MMBtu/hr |
16 |
0.74 SO2 |
Regulation 1.02, Appendix A |
Cold solvent parts washers with secondary reservoir (previous U12, see unit IA2) |
3 |
0.33 VOC |
Regulation 1.02, Appendix A |
Mechanical draft cooling tower |
1 |
2.58 PM10 |
Regulation 2.16, section 1.23 |
Lube oil demister vents |
3 |
0.4 VOC |
Regulation 2.16, section |
Equipment |
Quan. |
PTE (tpy) |
Regulation Basis |
|
|
|
1.23 |
660 gallons diesel tanks for emergency generator U18 |
1 |
0.027 VOC |
Regulation 1.02, Appendix A |
Emergency generators (See unit IA- EG) |
N/A |
N/A |
Regulation 2.16, section 1.23 |
Twelve (12) fuel or lubricating oils storage tanks, fifty one (51) emergency relief vents for boiler steam supply, One (1) lab exhaust systems, one (1) ash pond with wet storage, five (5) diesel storage tanks, and two (2) portable fuel storage tanks (< 500 gal) are delisted from the insignificant activities due to their trivial emissions (< 0.01 tpy) under normal operation. |
1) Insignificant Activities identified in District Regulation 1.02 Appendix A may be subject to size or production rate disclosure requirements.
2) Insignificant Activities identified in District Regulation 1.02 Appendix A shall comply with generally applicable requirements.
3) Activities identified in Regulation 1.02, Appendix A, may not require a permit and may be insignificant with regard to application disclosure requirements but may still have generally applicable requirements that continue to apply to the source and must be included in the permit.
4) Emissions from Insignificant Activities shall be reported in conjunction with the reporting of annual emissions of the facility as required by the District.
5) In lieu of recording annual throughputs and calculating actual annual emissions, the owner or operator may elect to report the pollutant Potential To Emit (PTE) quantity listed in the Insignificant Activities table, as the annual emission for each piece of equipment.
6) The Insignificant Activities Table is correct as of the date the permit was proposed for review by U.S. EPA, Region 4.
7) The owner or operator shall submit an updated list of Insignificant Activities whenever changes in equipment located at the facility occur that cause changes to the plant wide emissions.
Emission Unit IA1: Gasoline storage tank
IA1 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.40 |
Standards of Performance for Gasoline Transfer to Motor Vehicles (Stage II Vapor Recovery) |
1.3 |
7.15 |
Standards of Performance for Gasoline Transfer to New Service Station Storage Tanks (Stage I Vapor Recovery) |
1, 2, 3.1, 3.3, 3.4, 3.6, 3.7, 3.8, and 5 |
IA1 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
E17 |
One (1) Stage I gasoline refueling station, including one 560 gallon unleaded gasoline storage tank |
6.40 and 7.15 |
N/A |
IA1 Control Devices:
There are no control devices associated with emission unit IA1.
IA1 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
1) Submerged fill pipe; (Regulation 7.15, section 3.1.1)
2) If the gasoline storage tank is equipped with a separate gauge well, a gauge well drop tube shall be installed which extends to within six inches of the bottom of the tank; (Regulation 7.15, section 3.1.2)
3) Vent line restrictions on the affected facility; and (Regulation 7.15, section 3.1.3)
4) Vapor balance system and vapor tight connections on the liquid fill and vapor return hoses. The cross-sectional area of the vapor return hose and any other vapor return passages in the circuit connecting the vapor space in the service station tank to that of the truck tank must be at least 50% of the liquid fill hose cross- sectional area for each tank and free of flow restrictions to achieve acceptable recovery. The vapor balance equipment must be maintained according to the manufacturer’s specifications. The type, size and design of the vapor balance system are subject to the approval of the District. (Regulation 7.15, section 3.1.4)
1) All fill tubes shall be equipped with vapor-tight covers including gaskets, (Regulation 7.15, section 3.8.1)
2) All dry breaks shall have vapor-tight seals and shall be equipped with vapor-tight covers or dust covers, (Regulation 7.15, section 3.8.2)
3) All vapor return passages shall be operated so there can be no obstruction of vapor passage from the storage tank back to the delivery vehicle, (Regulation 7.15, section 3.8.3)
4) All storage tank vapor return pipes and fill pipes without dry breaks shall be equipped with vapor-tight covers including gaskets, and (Regulation 7.15, section 3.8.4)
5) All hoses, fittings, and couplings shall be in a vapor-tight condition. (Regulation 7.15, section 3.8.5)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 2)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the following records for a minimum of 5 years and make the records readily available to the District upon request.
VOC
The owner or operator shall keep a record of the amount of throughput of gasoline per month to determine compliance with Specific Condition S1.vi. (Regulation 6.40, section 3.1.1)
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit annual compliance reports that include the information in this section.
VOC
The owner or operator shall submit a report by April 15th every year showing that they are still exempt from Regulation 6.40. (Regulation 6.40, section 2.2.1)
IA1 Comments
Emission Unit IA2: Parts washers with secondary reservoirs
IA2 Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
6.18 |
Standards of Performance for Solvent metal Cleaning Equipment |
1 through 6 |
IA2 Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
E26a, b, c, d, e |
Five (5) parts washers each equipped with a secondary reservoir |
6.18 |
N/A |
Note: Two of the five parts washers in this unit will be removed prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and becomes operational. Three parts washers will still be in service after November 1, 2015. |
IA2 Control Devices:
There are no control devices associated with emission unit IA2.
IA2 Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
VOC
covered container may contain a device that allows pressure relief, but does not allow liquid solvent to drain from the container. (Regulation 6.18, section 4.2.1)
The owner or operator shall shut down the existing emission unit U4, U5, U6, U7, U8, U10, IA1 (previous U9), two parts washers of IA2 (previous U12), and U14 prior to November 1, 2015 when the new emission unit U15, U16, and U18 complete shakedown and become operational. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days. (Regulation 2.05) (40 CFR 52.21(b)(3)(viii)) (See Comment 2)
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
VOC
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit quarterly compliance reports that include the information in this section.
VOC
There are no routine compliance reporting requirements for Regulation 6.18.
IA2 Comments
Emission Unit IA-EG: Emergency generators
IA-EG Applicable Regulations:
FEDERALLY ENFORCEABLE REGULATIONS |
||
Regulation |
Title |
Applicable Sections |
40 CFR 63, Subpart ZZZZ |
National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines |
63.6603, 6604, 6605, 6625, 6640, 6645, 6655 |
40 CFR 60, Subpart IIII |
Standards of Performance for Stationary Compression Ignition Internal Combustion Engines |
60.4200 – 4219 |
IA-EG Equipment:
Emission Point |
Description |
Applicable Regulation |
Control ID |
Stack ID |
E-EG |
Emergency diesel generators that installed after July 11, 2005 and manufactured after April 1, 2006, with a maximum engine power less than or equal to 500 HP and located at a major/area source of HAP. |
40 CFR 63, Subpart ZZZZ, 40 CFR 60, Subpart IIII |
N/A |
N/A |
IA-EG Control Devices:
There are no control devices associated with this equipment.
IA-EG Specific Conditions
S1. Standards (Regulation 2.16, section 4.1.1)
Table 1 Emission standards for Pre-2007 model (40 CFR 60, Subpart IIII)
Maximum engine power |
Emission standards in g/KW-hr (g/HP-hr) |
||||
NMHC + NOX |
HC |
NOX |
CO |
PM |
|
kW < 8 (hp < 11) |
10.5 (7.8) |
|
|
8.0 (6.0) |
1.0 (0.75) |
8 ≤ kW < 19 (11 ≤ hp < 25) |
9.5 (7.1) |
|
|
6.6 (4.9) |
0.80 (0.60) |
19 ≤ kW < 37 (25 ≤ hp < 50) |
9.5 (7.1) |
|
|
5.5 (4.1) |
0.80 (0.60) |
37 ≤ kW < 56 (50 ≤ hp < 75) |
|
|
9.2 (6.9) |
|
|
56 ≤ kW < 75 (75 ≤ hp < 100) |
|
|
9.2 (6.9) |
|
|
75 ≤ kW < 130 (100 ≤ hp < 175) |
|
|
9.2 (6.9) |
|
|
130 ≤ kW < 225 (175 ≤ hp < 300) |
|
1.3 (1.0) |
9.2 (6.9) |
11.4 (8.5) |
0.54 (0.40) |
225 ≤ kW < 375 (300 ≤ hp < 500) |
|
1.3 (1.0) |
9.2 (6.9) |
11.4 (8.5) |
0.54 (0.40) |
Table 2 EPA Tier 1-4 Nonroad Diesel Engine Emission Standardsa, g/kW-hr (g/bhp-hr)
Maximum Engine Power |
Tier |
Model Yearb |
NOx |
HC |
NMHC +NOx |
CO |
PM |
kW < 8 (hp < 11) |
Tier 2/Tier 3 |
2005 |
– |
– |
7.5 (5.6) |
8.0 (6.0) |
0.8 (0.6) |
Tier 4 |
2008 |
– |
– |
7.5 (5.6) |
8.0 (6.0) |
0.4c (0.3) |
|
8 ≤ kW < 19 (11 ≤ hp < 25) |
Tier 2/Tier 3 |
2005 |
– |
– |
7.5 (5.6) |
6.6 (4.9) |
0.8 (0.6) |
Tier 4 |
2008 |
– |
– |
7.5 (5.6) |
6.6 (4.9) |
0.4 (0.3) |
|
19 ≤ kW < 37 (25 ≤ hp < 50) |
Tier 2/Tier 3 |
2004 |
– |
– |
7.5 (5.6) |
5.5 (4.1) |
0.6 (0.45) |
Tier 4 |
2008 |
– |
– |
7.5 (5.6) |
5.5 (4.1) |
0.3 (0.22) |
|
2013 |
– |
– |
4.7 (3.5) |
5.5 (4.1) |
0.03 (0.022) |
||
37 ≤ kW < 56 (50 ≤ hp < 75) |
Tier 2 |
2004 |
– |
– |
7.5 (5.6) |
5.0 (3.7) |
0.4 (0.3) |
Tier 3 |
2008 |
– |
– |
4.7 (3.5) |
5.0 (3.7) |
0.3d (0.22) |
|
Tier 4 |
2013 |
– |
– |
4.7 (3.5) |
5.0 (3.7) |
0.03 (0.022) |
|
56 ≤ kW < 75 (75 ≤ hp < 100) |
Tier 2 |
2004 |
– |
– |
7.5 (5.6) |
5.0 (3.7) |
0.4 (0.3) |
Tier 3 |
2008 |
– |
– |
4.7 (3.5) |
5.0 (3.7) |
0.4 (0.3) |
|
Tier 4 |
2012- 2014e |
0.4 (0.3) |
0.19 (0.14) |
– |
5.0 (3.7) |
0.02 (0.015) |
|
75 ≤ kW < 130 (100 ≤ hp < 175) |
Tier 2 |
2003 |
– |
– |
6.6 (4.9) |
5.0 (3.7) |
0.3 (0.2) |
Tier 3 |
2007 |
– |
– |
4.0 (3.0) |
5.0 (3.7) |
0.3 (0.2) |
|
Tier 4 |
2012- 2014e |
0.4 (0.3) |
0.19 (0.14) |
– |
5.0 (3.7) |
0.02 (0.015) |
|
130 ≤ kW < 225 (175 ≤ hp < 300) |
Tier 2 |
2003 |
– |
– |
6.6 (4.9) |
3.5 (2.6) |
0.2 (0.15) |
Tier 3 |
2006 |
– |
– |
4.0 (3.0) |
3.5 (2.6) |
0.2 (0.15) |
|
Tier 4 |
2011- 2014f |
0.4 (0.3) |
0.19 (0.14) |
– |
3.5 (2.6) |
0.02 (0.015) |
|
225 ≤ kW ≤ 375 (300 ≤ hp ≤ 500) |
Tier 3 |
2006 |
– |
– |
4.0 (3.0) |
3.5 (2.6) |
0.2 (0.15) |
Tier 4 |
2011- 2014f |
0.4 (0.3) |
0.19 (0.14) |
– |
3.5 (2.6) |
0.02 (0.015) |
a Emission standards from 40 CFR 89.112 Table 1 for Tier 1-3 engines and 40 CFR 1039.101 Table 1 for Tier 4 engines.
b The model years listed indicate the model years for which the specified tier of limits take effect.
c Hand-startable, air-cooled, DI engines may be certified to Tier 2 standards through 2009 and to an optional PM standard of 0.6 g/kW-hr starting in 2010
d 0.4 g/kWh (Tier 2) if manufacturer complies with the 0.03 g/kW-hr standard from 2012
e PM/CO: full compliance from 2012; NOx/HC: Option 1 (if banked Tier 2 credits used) – 50% engines shall comply in 2012-2013; Option 2 (if no Tier 2 credits claimed) – 25% engines shall comply in 2012-2014, with full compliance from 2014.12.31
f PM/CO: full compliance from 2011; NOx/HC: 50% engines shall comply in 2011-2013
Table 3 EPA Tier 1-4 Nonroad Diesel Engine Family Emission Limits, g/kW-hr (g/bhp-hr)
Maximum Engine Power |
Tier |
Model Yeara |
NOx |
NMHC +NOx |
PM |
kW < 8 (hp < 11) |
Tier 2/Tier 3 |
2005 |
– |
10.5 (7.8) |
1.0 (0.7) |
Tier 4 |
– |
– |
10.5 (7.8) |
0.8 (0.6) |
|
8 ≤ kW < 19 (11 ≤ hp < 25) |
Tier 2/Tier 3 |
2005 |
– |
9.8 (7.3) |
0.8 (0.6) |
Tier 4 |
– |
– |
9.5 (7.1) |
0.8 (0.6) |
Maximum Engine Power |
Tier |
Model Yeara |
NOx |
NMHC +NOx |
PM |
19 ≤ kW < 37 (25 ≤ hp < 50) |
Tier 2/Tier 3 |
2004 |
– |
9.5 (7.1) |
0.8 (0.6) |
Tier 4 |
– |
– |
7.5 (5.6) |
0.05 (0.037) |
|
37 ≤ kW < 56 (50 ≤ hp < 75) |
Tier 2 |
2004 |
– |
11.5 (8.6) |
1.2 (0.9) |
Tier 3 |
2008 |
– |
7.5 (5.6) |
1.2 (0.9) |
|
Tier 4 |
– |
– |
7.5 (5.6) |
0.05 (0.037) |
|
56 ≤ kW < 75 (75 ≤ hp < 100) |
Tier 2 |
2004 |
– |
11.5 (8.6) |
1.2 (0.9) |
Tier 3 |
2008 |
– |
7.5 (5.6) |
1.2 (0.9) |
|
Tier 4 |
– |
0.8 (0.6) |
– |
0.04 (0.03) |
|
75 ≤ kW < 130 (100 ≤ hp < 175) |
Tier 2 |
2003 |
– |
11.5 (8.6) |
1.2 (0.9) |
Tier 3 |
2007 |
– |
6.6 (4.9) |
1.2 (0.9) |
|
Tier 4 |
– |
0.8 (0.6) |
– |
0.04 (0.03) |
|
130 ≤ kW < 225 (175 ≤ hp < 300) |
Tier 2 |
2003 |
– |
10.5 (7.8) |
0.54 (0.04) |
Tier 3 |
2006 |
– |
6.6 (4.9) |
0.54 (0.4) |
|
Tier 4 |
– |
0.8 (0.6) |
– |
0.04 (0.03) |
|
225 ≤ kW ≤ 375 (300 ≤ hp ≤ 500) |
Tier 3 |
2006 |
– |
6.4 (4.8) |
0.54 (0.4) |
Tier 4 |
– |
0.8 (0.6) |
– |
0.04 (0.03) |
Table 4 EPA Tier 1-4 Smoke Emission Standards
Maximum Engine Power |
Tier |
Smoke Emission Standards |
0 < kW ≤ 375 (0 < hp ≤ 500) |
Tier 1 |
(1) 20% during the acceleration mode (2) 15% during the lugging mode; or (3) 50% during the peaks in either the acceleration or lugging modes. |
Tier 2 |
||
Tier 3 |
||
Tier 4 |
1) Operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer’s emission- related written instructions; (40 CFR 60.4211(a)(1))
2) Change only those emission-related settings that are permitted by the manufacturer; (40 CFR 60.4211(a)(2))
1) Purchasing an engine certified according to 40 CFR part 89 or 40 CFR part 94, as applicable, for the same model year and maximum engine power. The engine shall be installed and configured according to the manufacturer’s specifications. (40 CFR 60.4211(b)(1))
2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test shall have been conducted using the same methods specified in this subpart and these methods shall have been followed correctly. (40 CFR 60.4211(b)(2))
3) Keeping records of engine manufacturer data indicating compliance with the standards. (40 CFR 60.4211(b)(3))
4) Keeping records of control device vendor data indicating compliance with the standards. (40 CFR 60.4211(b)(4))
5) Conducting an initial performance test to demonstrate compliance with the emission standards according to the requirements specified in the Testing section of this permit, as applicable. (40 CFR 60.4211(b)(5))
demonstrate compliance according to one of the methods specified in paragraphs (e)(1) or (2) of this section. (40 CFR 60.4211(e))
1) Purchasing, or otherwise owning or operating, an engine certified to the emission standards in Table 2, Table 3, or the Testing section of this permit, as applicable. (40 CFR 60.4211(e)(1))
2) Conducting a performance test to demonstrate initial compliance with the emission standards according to the requirements specified in the Testing section of this permit, as appropriate. The test shall be conducted within 60 days after the engine commences operation after the modification or reconstruction. (40 CFR 60.4211(e)(2))
1) There is no time limit on the use of emergency stationary ICE in emergency situations. (40 CFR 60.4211(f)(1))
2) The owner or operator may operate the emergency stationary ICE for any combination of the purposes specified in 60 CFR 60.4211(f)(2)(i) through (iii) for a maximum of 100 hours per calendar year. Any operation for non-emergency situations as allowed by 60 CFR 60.4211(f)(3) counts as part of the 100 hours per calendar year allowed by this paragraph. (40 CFR 60.4211(f)(2)).
(a) Emergency stationary ICE may be operated for maintenance checks and readiness testing, provided that the tests are recommended by federal, state or local government, the manufacturer, the vendor, the regional transmission organization or equivalent balancing authority and transmission operator, or the insurance company associated with the engine. The owner or operator may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that federal, state, or local
standards require maintenance and testing of emergency ICE beyond 100 hours per calendar year. (40 CFR 60.4211(f)(2)(i))
(b) Emergency stationary ICE may be operated for emergency demand response for periods in which the Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP-002-3, Capacity and Energy Emergencies (incorporated by reference, see 40 CFR 60.17), or other authorized entity as determined by the Reliability Coordinator, has declared an Energy Emergency Alert Level 2 as defined in the NERC Reliability Standard EOP-002-3. (40 CFR 60.4211(f)(2)(ii))
(c) Emergency stationary ICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency. (40 CFR 60.4211(f)(2)(iii))
3) Emergency stationary ICE may be operated for up to 50 hours per calendar year in non-emergency situations. The 50 hours of operation in non-emergency situations are counted as part of the
100 hours per calendar year for maintenance and testing and emergency demand response provided in 40 CFR 60.4211(f)(2). Except as provided in 40 CFR 60.4211(f)(3)(i), the 50 hours per calendar year for non-emergency situations cannot be used for peak shaving or non-emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity. (40 CFR 60.4211(f)(3))
(a) The 50 hours per year for non-emergency situations can be used to supply power as part of a financial arrangement with another entity if all of the following conditions are met: (40 CFR 60.4211(f)(3)(i))
(i) The engine is dispatched by the local balancing authority or local transmission and distribution system operator; (40 CFR 60.4211(f)(3)(i)(A))
(ii) The dispatch is intended to mitigate local transmission and/or distribution limitations so as to avert potential voltage collapse or line overloads that could lead to the interruption of power supply in a local area or region. (40 CFR
60.4211(f)(3)(i)(B))
(iii) The dispatch follows reliability, emergency operation or similar protocols that follow specific NERC, regional, state, public utility commission or local standards or guidelines. (40 CFR 60.4211(f)(3)(i)(C))
(iv) The power is provided only to the facility itself or to support the local transmission and distribution system. (40 CFR 60.4211(f)(3)(i)(D))
(v) The owner or operator identifies and records the entity that dispatches the engine and the specific NERC, regional, state, public utility commission or local standards or guidelines that are being followed for dispatching the engine. The local balancing authority or local transmission and distribution system operator may keep these records on behalf of the engine owner or operator. (40 CFR 60.4211(f)(3)(i)(E))
Beginning October 1, 2010, the owner or operator of a stationary CI ICE subject to this subpart with a displacement of less than 30 liters per cylinder that uses diesel fuel shall use diesel fuel that meets the requirements of 40 CFR 80.510(b) for nonroad diesel fuel, except that any existing diesel fuel purchased (or otherwise obtained) prior to October 1, 2010, may be used until depleted: (40 CFR 60.4207(b))
1) Sulfur content: 15 parts per million (ppm) maximum for NR diesel fuel. (40 CFR 80.510(b)(1)(i))
2) A minimum cetane index of 40; or (40 CFR 80.510(b)(2)(i))
3) A maximum aromatic content of 35 volume percent. (40 CFR 80.510(b)(2)(ii))
S2. Monitoring and Record Keeping (Regulation 2.16, sections 4.1.9.1 and 4.1.9.2)
The owner or operator shall maintain the required records for a minimum of 5 years and make the records readily available to the District upon request.
engines shall install a non-resettable hour meter prior to startup of the engine. (40 CFR 60.4209(a))
Table 5 Labeling and Recordkeeping Requirements for New Stationary Emergency Engines
Engine Power |
Starting Model Year |
19 ≤ kW < 56 (25 ≤ hp < 75) |
2013 |
56 ≤ kW < 130 (75 ≤ hp < 175) |
2012 |
130 ≤ kW ≤ 375 (175 ≤ hp ≤ 500) |
2011 |
The owner or operator shall maintain records of the fuel MSDS sheets and receipts showing dates, amounts of fuel purchased, sulfur content of fuel purchased and supplier’s name and address, to show compliance with Specific Condition S1.b.
S3. Reporting (Regulation 2.16, section 4.1.9.3)
The owner or operator shall submit compliance reports that include the information in this section.
1) Identification of all periods during which a deviation occurred;
2) A description, including the magnitude, of the deviation;
3) If known, the cause of the deviation;
4) A description of all corrective actions taken to abate the deviation; and
5) If no deviations occur during a reporting period, the report shall contain a negative declaration.
1) The report shall contain the following information: (40 CFR 60.4214(d)(1))
(a) Company name and address where the engine is located. (40 CFR 60.4214(d)(1)(i))
(b) Date of the report and beginning and ending dates of the reporting period. (40 CFR 60.4214(d)(1)(ii))
(c) Engine site rating and model year. (40 CFR 60.4214(d)(1)(iii))
(d) Latitude and longitude of the engine in decimal degrees reported to the fifth decimal place. (40 CFR 60.4214(d)(1)(iv))
(e) Hours operated for the purposes specified in 40 CFR 60.4211(f)(2)(ii) and (iii), including the date, start time, and end time for engine operation for the purposes specified in 40 CFR 60.4211(f)(2)(ii) and (iii). (40 CFR 60.4214(d)(1)(v))
(f) Number of hours the engine is contractually obligated to be available for the purposes specified in 40 CFR 60.4211(f)(2)(ii) and (iii). (40 CFR 60.4214(d)(1)(vi))
(g) Hours spent for operation for the purposes specified in 40 CFR 60.4211(f)(3)(i), including the date, start time, and end time for engine operation for the purposes specified in 40 CFR 60.4211(f)(3)(i). The report shall also identify the entity that dispatched the engine and the situation that necessitated the dispatch of the engine. (40 CFR 60.4214(d)(1)(vii))
2) The first report shall cover the calendar year 2015 and shall be submitted no later than March 31, 2016. Subsequent reports for each calendar year shall be submitted as required by your operating permit. (40 CFR 60.4214(d)(2))
3) The report shall be submitted electronically using the subpart specific reporting form in the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA’s Central Data Exchange (CDX) (www.epa.gov/cdx). However, if the reporting form specific to this subpart is not available in CEDRI at the time that the report is due, the written report shall be submitted to the Administrator at the appropriate address listed in 40 CFR 60.4. (40 CFR 60.4214(d)(3))
There are no routine compliance reporting requirements for this equipment.
S4. Testing (Regulation 2.16, section 4.1.9.3)
The owner or operator of stationary CI ICE with a displacement of less than 30 liters per cylinder who conduct performance tests pursuant to this subpart shall do so according to the following paragraphs: (40 CFR 60.4212)
the same number of decimal places as the applicable standard in Table 2 or Table 3, determined from the following equation: (40 CFR 60.4212(c))
NTE requirement for each pollutant = (1.25) × (STD) (Eq. 1)
Where:
STD = The standard specified for that pollutant in Table 2 or Table 3.
Alternatively, stationary CI ICE that are complying with the emission standards for new CI engines in Table 2 or Table 3 may follow the testing procedures specified in 40 CFR 60.4213 of this subpart, as appropriate.
Where:
STD = The standard specified for that pollutant in Table 1.
Alternatively, stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in Table 1 may follow the testing procedures specified in 40 CFR 60.4213, as appropriate.
The owner or operator shall construct all equipment in such a manner that the following testing requirements can be performed.
be used for compliance testing, the process operating parameters that will be monitored during the performance test, and the control device performance indicators (e.g. pressure drop, minimum combustion chamber temperature) that will be monitored during the performance test. The compliance test plans shall be furnished to the District at least 30 days prior to the actual date of the performance test. Attached to the permit is a Protocol Checklist for Performance Test for the information to be submitted in the protocol.
IA-EG Comment
Attachment A – Protocol Checklist for a Performance Test
A completed protocol should include the following information:
□ 1. Facility name, location, and ID #;
□ 2. Responsible Official and environmental contact names;
□ 3. Permit numbers which are requiring the test to be conducted;
□ 4. Test methods to be used (i.e. EPA Method 1, 2, 3, 4, and 5);
□ 5. Alternative test methods or description of modifications to the test methods to be used;
□ 6. Purpose of the test including equipment, and pollutant to be tested; the purpose may be described in the permit which requires the test to be conducted or may be to show compliance with a federal regulation or emission standard;
□ 7. Tentative test dates (these may change but the District will need final notice at least 10 days in advance of the actual test dates in order to arrange for observation);
□ 8. Maximum rated production capacity of the system;
□ 9. Production-rate goal planned during the performance test for demonstration of compliance (if appropriate based on limits);
□ 10.Method to be used for determining rate of production during the performance test;
□ 11. Method to be used for determining rate of production during subsequent operations of the process equipment to demonstrate compliance;
□ 12. Description of normal operation cycles;
□ 13. Discussion of operating conditions that tend to cause worse case emissions; it is especially important to clarify this if worst case emissions do not come from the maximum production rate;
□ 14. Process flow diagram;
□ 15. List the type and manufacturer of the control equipment if any;
□ 16. List the control equipment (baghouse, scrubber, condenser, etc.) parameter to be monitored and recorded during the performance test; note that this data will be used to ensure representative operation during subsequent operations. These parameters can include pressure drops, flow rates, pH, and temperature. The values achieved during the test may be required during subsequent operations to describe what pressure drops, etcetera, are indicative of good operating performance; and
□ 17. How quality assurance and accuracy of the data will be maintained, including;
□ 18. Pipe, duct, stack, or flue diameter to be tested;
□ 19. Distances from the testing sample ports to the nearest upstream and downstream flow disturbances such as bends, valves, constrictions, expansions, and exit points for outlet and additionally for inlet;
□ 20. Determine number of traverse points to be tested for outlet and additionally for inlet if required using Appendix A-1 to 40 CFR Part 60;
□ 21. The Stack Test Review fee shall be submitted with each stack test protocol.
Attachment B – NOx RACT Plan – Amendment 2 Part 1 of NOx RACT Plan
(Part 1 of the NOx RACT Plan will remain effective until the LG&E/CRGS shuts down the coal-fired boilers.)
Unit 4 0.52 lb/MMBtu heat input
Unit 5 0.52 lb/MMBtu heat input
Unit 6 0.47 lb/MMBtu heat input
If no deviation occurred during the calendar quarter, the report shall contain a negative declaration. Each report shall be submitted within 30 days following the end of the calendar quarter.
The District’s determination of approval of any alternative requirements is not binding on EPA. Noncompliance with any alternative requirement established pursuant to the Title V Operating Permit process constitutes a violation of this NOx RACT Plan.
Part 2 of NOx RACT Plan
(Part 2 of this NOx RACT Plan will be effective when the new NGCC unit and the associated equipment start to be operated, and the coal-fired boilers are shut down and Part 1 of this Plan is voided.)
The District’s determination of approval of any alternative requirements is not binding on EPA. Noncompliance with any alternative requirement established pursuant to the Title V Operating Permit process constitutes a violation of this NOx RACT Plan.
History: Approved 11-8-99, effective 1-1-00; amended a1/10-18-00, effective 1-1-01; amended a2/07-18-12, effective 07-18/12
Appendix A to NOx RACT Plan (Requirements for NOx CEMS)
Appendix B, District regulations, District permit conditions, or this NOx RACT Plan, or
When the certified primary monitoring system is operating and not out-of-control as defined in 40 CFR 75.24, only data from the certified primary monitoring system shall be reported as valid, quality-assured data. Thus, data from a backup CEMS may be reported as valid, quality-assured data only when a backup CEMS is operating and not out-of-control as defined in 40 CFR 75.24 or in the applicable reference method in 40 CFR 60 Appendix A and when the certified primary monitoring system is not operating or is operating but out-of-control. A particular monitor may be designated both as a certified primary monitor for one unit and as a certified redundant backup monitor for another unit.
maintain, and quality assure a continuous moisture monitoring system, as defined in 40 CFR 75.11(b)(2). Notwithstanding this requirement, if Equation 19-3, 19-4 or 19-8 in Method 19 in Appendix A to 40 CFR Part 60 is used to measure NOx emission rate, the following fuel-specific default moisture percentages shall be used in lieu of the default values specified in 40 CFR 75.11(b)(1): 5.0%, for anthracite coal; 8.0% for bituminous coal; 12.0% for sub-bituminous coal; 13.0% for lignite coal; and 15.0% for wood.
The LG&E/CRGS shall prepare and maintain a monitoring plan as specified in 40 CFR 75.53. The monitoring plan shall be submitted to the District no later than 45 days prior to the first scheduled certification test.
gases as defined in 40 CFR 72.2 and 40 CFR 75 Appendix A were used to conduct calibration error testing,
dilution type reference method systems, for the 3-point, pre-test system calibration error test) and for any subsequent recalibrations,
Attachment C – Plant-wide Odor, Fugitive Dust, and Maintenance Emissions Control Plan Cane Run Generating Station
(Submitted 2/13/2013 and 8/16/2013; Adopted by the Board 4/17/2013 and 11/20/2013)
Executive Summary
Louisville Gas and Electric Company (LG&E) is required to maintain and operate the Cane Run Generating Station in a manner consistent with good air pollution control practices for minimizing emissions, as defined in KRS Chapter 77 Air Pollution Control.
The purpose of this plan is to identify and commit to “reasonable precaution” control measures that will minimize fugitive particulate emissions, control objectionable odors that may originate on plant property, and prevent unnecessary emissions. This plan has been developed at the request of the Louisville Metro Air Pollution Control District (APCD).
Louisville Metro
Air Pollution Control District 850 Barret Ave.
Louisville, KY 40204-1745
502-574-6000
Introduction
This plan identifies potential sources of fugitive particulate emissions and potential objectionable odors from equipment and processes at LG&E’s Cane Run Generating Station, 5252 Cane Run Road. The plan also identifies measures to further control potential dust from these sources. The sources identified by the District include: the Unit 4/5 Sludge Processing Plant (SPP), the landfill, various ash ponds and ditches, 4/5 Fly Ash transfer Line, maintenance procedures associated with the generating unit stacks, construction activities and other sources of fugitive dust (piles, roads, yards). This plan is divided into four sections:
Section 1 – Site Description
LG&E’s Cane Run Generating Station (Cane Run) is located in southwestern Louisville at 5252 Cane Run Road. Cane Run generates electric energy for local and remote distribution. Coal is the primary fuel used to fire three (3) commercial boilers for generation of electricity via steam turbines and generators. Waste solids from the Flue Gas Desulfurization systems are mixed with fly ash and fixation lime, and the resulting inert lightweight concrete material is placed in an on- site landfill.
The Cane Run site consists of 510 acres with river frontage on the Ohio River. The existing operation is spread throughout the acreage. Coal is delivered by rail car with shipments placed in a storage pile.
The parking areas are asphalt surfaced and located in several areas on the site, including the parking area directly beside the security gate/office for use by contractors and employees.
The aerial map below highlights the various potential sources and areas of concern that are discussed within this plan.
Cane Run Aerial Site Map
Section 2 – Description of Potential Sources of Dust or Odor at Cane Run Generating Station
Potential Sources:
Unit 4/5 SPP
The Unit 4/5 SPP is located on the southwest side of the plant site, in front of the landfill. The 4/5 SPP receives transported fly ash via a blower system, which includes a transfer line from a central bin where fly ash has been collected from hoppers located around each of the three coal- fired boilers. The fly ash is mixed with de-watered scrubber sludge to create a physically and environmentally stable product that is stored onsite in the plant¡¦s landfill.
The 4/5 SPP pug mill mixer incorporates a wet cyclone dust collector and a HEPA filtering system contained within the 4/5 SPP building.
During maintenance activities or general operation, on an as-needed basis, a roof vent may be utilized for ventilation.
Potential Fugitive Dust Sources from the 4/5 SPP include:
Potential Point Source for Dust Emissions from the 4/5 SPP Include:
Material Storage
The material storage yard is located in the middle of the property near the ash pond and consists of a stockpile of bituminous coal. Coal is delivered by railcar and transferred to an onsite stockpile. Under normal operation, the facility may incur up to 100 truck trips per weekday divided between trucks delivering raw materials for production and large off road dump trucks hauling Poz-o-tec to be placed in the landfill. Raw powdered bulk materials (lime, soda ash, and fly ash) used in the production of power is delivered to the site by pneumatic tanker trailer and the materials are blown into silos which all have bag-houses to mitigate dust during transfer activity.
Potential fugitive dust from material storage includes:
Landfill
The Cane Run landfill contains Poz-o-tec which is an inert, lightweight concrete that is made by mixing FGD solids (calcium sulfite, and sulfate), fly ash, and fixation lime. An excavator is used
at the SPP stacker pads to load Poz-o-tec into the dump trucks which are placed in the landfill.
Potential fugitive dust from the landfill may be caused by:
Federal Highway Administration (FHWA) has conducted extensive research concerning pozzolan materials (fly ash, Poz-o-tec, etc.) in use as roadway base material and slope stabilizers. Data indicates that material with higher fly ash content such as Poz-o-tec has less moisture infiltration than standard concrete and has a structure that provides a denser product that allows fewer voids between particles. This would indicate that freeze-thaw erosion potential is negligible and would not be a source of fugitive emissions from the landfill. Data previously submitted to APCD shows that the density of Poz-o-tec is similar to that of Kentucky clay soils. This landfill was engineered to meet continuous compliance with Kentucky Division Waste Management structural requirements and measurements.
Unpaved Roads
Unpaved roads at the Cane Run site are typically graveled at #57 grade. The ash pond roads have been sealed as a dust control measure and traffic is limited. Vehicle access to unpaved roads is limited to contractors and employees performing required operational duties.
Potential fugitive dust from unpaved roads may be caused by:
Paved Roads
The paved roads are asphalt or concrete surfaced and traffic is limited to contractors and employees.
Potential fugitive dust from paved roads may include:
Fly Ash Transfer Line
Due to a recent dust event that resulted from a crack that developed in the fly ash transfer line, LG&E performed an eight year look back of its past maintenance records and was unable to find any other incidents of this nature for this equipment. The majority of the transfer line is located below ground and the section of pipe that cracked was above ground at an “elbow joint”.
Potential fugitive dust from fly ash transfer line may include:
Unit 4, 5, and 6 Stack Maintenance Activities
Typically once or twice per year each of the generating units is off-line to perform scheduled routine maintenance, which includes balancing fans. In addition, it may be necessary to balance fans more often if vibration issues arise. In order to balance the fans, they must be operating. During balancing, residual fly ash can be dislodged and picked up by the draft and exit the stack. Potential emissions from maintenance activities may include:
Ash Pond, E-Pond, South Basin and East Ditch
Due to the build-up of bacteria, odors may result when cleaning materials from inactive areas of the ponds and east ditch. The drainage ditch south of the 4/5 SPP no longer exists due to the construction of the MSE wall, thus it is has been removed from this plan.
Potential objectionable odors from ponds and ditches may include:
Construction Activities
A new natural gas combined cycle (NGCC) electricity generating facility will be constructed adjacent to the existing Cane Run Generating Station. Construction activities will take place until the completion of the new plant. Potential dust emissions from construction activities can vary significantly, depending on the level/type of activity and weather conditions.
Potential fugitive dust from construction activities may include:
Section 3 – Control Measures to Minimize Emissions Site Monitoring
during hauling and placement activities and will assess the need for dust control on a continuing basis.
Unit 4/5 SPP
(2) smart transmitters. The project scope included the purchase, removal, and installation of control system. The major objective of this project is that once an off-normal condition occurs at the 4&5 SPP, process controls will immediately shut down the process, turn on water spray systems, and inform operators so that measures can be taken to further mitigate any potential dusting or other unfavorable event.
Hauling and Storage of Materials
Landfill
LG&E had previously proposed an installation of a fabric cover on the face of the steep slope behind the SPP. During the course of this evaluation, it was determined that the application of a fabric covering on the face of this slope is not the most viable option. In addition, a process of “hydro-mulching” was also considered. Hydro mulching is the process of applying moist mulch that contains seeds and tacking agents intended to adhere to the surface on which it is applied. However, with consideration of limitations during growing seasons and the proven effectiveness
of the application of dust suppressant (Gorilla-Snot®), the plant will manage sloped areas through application of the dust suppressant.
Unpaved Roads
Paved Roads
Fly Ash Transfer Line
Unit 4, 5, and 6 Stack Maintenance Activities
Cane Run has developed a fan balance procedure that includes ensuring the full FGD system is in service, monitoring the stacks with newly installed video cameras, and having the fans ramped up slowly to minimize dust entrainment. Fan balancing occurred four times in 2010, three times in 2011, and three times in 2012 prior to implementation of the fan balancing procedures.
Odor Control of Ash Pond, E-Pond, South Basin and East Ditch
Cane Run is in the process of eliminating the E-pond as a settlement control and will construct a South Basin located approximately north of the current E-Pond. The South Basin will provide settlement control for the Ash Pond closure site and landfill runoff and move the potential source of odor farther from the neighborhood. Once the landfill is closed, the East Ditch will no longer be a source for landfill runoff thus eliminating the potential for odors. During the process of closing the ash pond, Cane Run will perform the following measures to control odor from the site.
The previous measures have successfully mitigated the potential for objectionable odor as a result of plant operations. However, the scale of construction work at the plant presents a higher potential for this issue and therefore, the plant has commenced analysis of the following options to further reduce said potential. Implementation of one or more of these options (along with the previously discussed measures) will reduce these odors from objectionable to de minimis.
Construction Activities
Additional Measures
LG&E Cane Run Plant Manager will notify the District of any additional procedures that are implemented and will submit a revised dust control plan to reflect any new procedures.
The Plant Manager is responsible for implementing the procedures outlined in the dust control plan. The plan will be maintained on file at the Cane Run Generating Station for plant personnel to use and has been submitted to APCD for approval.
Plant Manager: David Tummonds
Section 4 – Primary Contact List
Personnel involved in activities that produce fugitive particulate emission and objectionable odors will continue to be made aware of the Cane Run Compliance Plan in place. The following primary contact list is intended for use only by personnel employed by the LMAPCD and is being provided for LMAPCD’s use as needed to obtain information regarding any questions or issues with equipment or processes contained within this plan. Mark Hussung should be used as the primary contact and Brandan Burfict as the secondary contact. In the absence of the plant manager, all operation, production and maintenance managers and on-shift operation supervisors have full authority to make the necessary dust mitigation decisions. The contacts listed below are appropriate during business hours and after business hours.
1) Mark Hussung, Environmental Compliance Supervisor, Cane Run Station 502-449-8857 (Office), 502-599-6320 (Cell)
2) Brandan Burfict, Environmental Engineer, Environmental Air Section 502-627-2791 (Office), 502-991-1113 (Cell)
3) David Tummonds, General Manager, Cane Run Station 502-449-8801 (Office), 502-381-4041 (Cell)
4) Park Payne, O & M Manager, Cane Run Station 502-449-8853 (Office), 502-939-5796 (Cell)
5) Steve Noland, Manager, Environmental Air Section, LGE/KU 502-627-2940 (office), 502-377-0340 (Cell)
*Note: The following attachments outline the standard operating procedures and other documents that are referenced in this plan. They include the training document that was used to train SPP operators, the Dust Suppressant Application Plan, fan balancing procedures and the dust awareness letter issued to contractors upon entering the plant property. The SOPs are current as of December 21, 2012 and may be changed as needed.
Attachment D – 40 CFR 75, Subpart G
The owner or operator shall comply with the following requirements unless there are more current promulgated regulations:
Specific Conditions
S1. Reporting Requirements for Continuous Emission Monitoring
1) Summarized test results. (40 CFR 75.59(a)(9)(i))
2) DAHS printouts of the CEMS data generated during the calibration error, linearity, cycle time, and relative accuracy tests. (40 CFR 75.59(a)(9)(ii))
3) For pollutant concentration monitor or diluent monitor relative accuracy tests at normal operating load: (40 CFR 75.59(a)(9)(iii))
(a) The raw reference method data from each run, i.e., the data under paragraph (a)(7)(iv)(Q) of 40 CFR 75.59 (usually in the form of a computerized printout, showing a series of one-minute readings and the run average); (40 CFR 75.59(a)(9)(iii)(A))
(b) The raw data and results for all required pre-test, post-test, pre-run and post-run quality assurance checks (i.e., calibration gas injections) of the reference method
analyzers, i.e., the data under paragraphs (a)(7)(iv)(E) through (a)(7)(iv)(N) of 40 CFR 75.59 (supporting information for RATA using Method 6C, 7E, or 3A); (40 CFR 75.59(a)(9)(iii)(B))
(c) The raw data and results for any moisture measurements made during the relative accuracy testing, i.e., the data under paragraphs (a)(7)(v)(A) through (a)(7)(v)(O) of 40 CFR 75.59 (supporting information for RATA using Method 4); and (40 CFR 75.59(a)(9)(iii)(C))
(d) Tabulated, final, corrected reference method run data (i.e., the actual values used in the relative accuracy calculations), along with the equations used to convert the raw data to the final values and example calculations to demonstrate how the test data were reduced. (40 CFR 75.59(a)(9)(iii)(D))
4) For relative accuracy tests for flow monitors: (40 CFR 75.59(a)(9)(iv))
(a) The raw flow rate reference method data, from Reference Method 2 (or its allowable alternatives) under appendix A to part 60 of this chapter, including auxiliary moisture data (often in the form of handwritten data sheets), i.e., the data under paragraphs (a)(7)(ii)(A) through (a)(7)(ii)(T), paragraphs (a)(7)(iii)(A) through (a)(7)(iii)(M), and, if applicable, paragraphs (a)(7)(v)(A) through (a)(7)(v)(O) of 40 CFR 75.59 (supporting information for RATA using Method 2 and Method 4) ; and (40 CFR 75.59(a)(9)(iv)(A))
(b) The tabulated, final volumetric flow rate values used in the relative accuracy calculations (determined from the flow rate reference method data and other necessary measurements, such as moisture, stack temperature and pressure), along with the equations used to convert the raw data to the final values and example calculations to demonstrate how the test data were reduced. (40 CFR 75.59(a)(9)(iv)(B))
5) Calibration gas certificates for the gases used in the linearity, calibration error, and cycle time tests and for the calibration gases used to quality assure the gas monitor reference method data during the relative accuracy test audit. (40 CFR 75.59(a)(9)(v))
6) Laboratory calibrations of the source sampling equipment. (40 CFR 75.59(a)(9)(vi))
7) A copy of the test protocol used for the CEMS certifications or recertifications, including narrative that explains any testing abnormalities, problematic sampling, and analytical conditions that required a change to the test protocol, and/or solutions to technical problems encountered during the testing program. (40 CFR 75.59(a)(9)(vii))
8) Diagrams illustrating test locations and sample point locations (to verify that locations are consistent with information in the monitoring plan). Include a discussion of any special traversing or measurement scheme. The discussion shall also confirm that sample points satisfy applicable acceptance criteria. (40 CFR 75.59(a)(9)(viii))
9) Names of key personnel involved in the test program, including test team members, plant contacts, agency representatives and test observers on site. (40 CFR 75.59(a)(9)(vix))
10) For testing involving use of EPA Protocol gases, the owner or operator shall record in electronic and hardcopy format the following information, as applicable: (40 CFR 75.59(a)(9)(x))
(a) On and after September 26, 2011, for each gas monitor, for both low and high measurement ranges, record the following information for the mid-level or high-level EPA Protocol gas (as applicable) that is used for daily calibration error tests, and the low-, mid-, and high-level gases used for quarterly linearity checks. For O2 , if purified air is used as the high-level gas for daily calibrations or linearity checks, record the following information for the low- and mid-level EPA Protocol gas used for linearity checks, instead: (40 CFR 75.59(a)(9)(x)(A))
(i) Gas level code; (40 CFR 75.59(a)(9)(x)(A)(1))
(ii) A code for the type of EPA Protocol gas used; (40 CFR 75.59(a)(9)(x)(A)(2))
(iii) The PGVP vendor ID issued by EPA for the EPA Protocol gas production site that supplied the EPA Protocol gas cylinder; (40 CFR 75.59(a)(9)(x)(A)(3))
(iv) The expiration date for the EPA Protocol gas cylinder; and (40 CFR 75.59(a)(9)(x)(A)(4))
(v) The cylinder number. (40 CFR 75.59(a)(9)(x)(A)(5))
(b) On and after September 26, 2011, for each usage of Reference Method 3A in appendix A-2 to part 60 of this chapter, or Method 6C or 7E in appendix A-4 to part 60 of this chapter performed using EPA Protocol gas for the certification, recertification, routine quality assurance or diagnostic testing (reportable diagnostics, only) of a Part 75 monitoring system, record the information required by paragraphs (a)(9)(x)(A)(1) through (5) of 40 CFR 75.59. See Condition S1.a.ii.(10)(a){(i) through (v). (40 CFR 75.59(a)(9)(x)(B))
11) On and after March 27, 2012, for all RATAs performed pursuant to 40 CFR 75.74(c)(2)(ii), section 6.5 of appendix A to this part and section 2.3.1 of appendix B to this part, and for all NOX emission testing performed pursuant to section 2.1 of appendix E to this part, or 40 CFR 75.19(c)(1)(iv), the owner or operator shall record the following information as provided by the AETB: (40 CFR 75.59(a)(9)(xi))
(a) The name, telephone number and e-mail address of the Air Emission Testing Body; (40 CFR 75.59(a)(9)(xi)(A))
(b) The name of each on-site Qualified Individual, as defined in § 72.2 of this chapter; (40 CFR 75.59(a)(9)(xi)(B))
(c) For the reference method(s) that were performed, the date(s) that each on-site Qualified Individual took and passed the relevant qualification exam(s) required by ASTM D7036-04 (incorporated by reference, see 40 CFR 75.6); and (40 CFR 75.59(a)(9)(xi)(C))
(d) The name and e-mail address of each qualification exam provider. (40 CFR 75.59(a)(9)(xi)(D))
1) Notification of initial certification testing and full recertification. Initial certification test notifications and notifications of full recertification testing under 40 CFR 75.20(b)(2) shall be submitted not later than 21 days prior to the first scheduled day of certification or recertification testing. In emergency situations when full recertification testing is required following an uncontrollable failure of equipment that results in lost data, notice shall be sufficient if provided within 2 business days following the date when testing is scheduled. Testing may be performed on a date other than that already provided in a notice under this subparagraph as long as notice of the new date is provided either in writing or by telephone or other means at least 7 days prior to the original scheduled test date or the revised test date, whichever is earlier. (40 CFR75.61(a)(1)(i))
2) Notification of certification retesting, and partial recertification testing. For retesting required following a loss of certification under 40 CFR 75.20(a)(5) or for partial recertification testing required under 40 CFR 75.20(b)(2), notice of the date of any required RATA testing or any required retesting under section 2.3 in appendix E to this part shall be submitted either in writing or by telephone at least 7 days prior to the first scheduled day of testing; except that in emergency situations when testing is required following an uncontrollable failure of equipment that results in lost data, notice shall be sufficient if provided within 2 business days following the date when testing is scheduled. Testing may be performed on a date other than that already provided in a notice under this subparagraph as long as notice of the new date is provided by telephone or other means at least 2 business days prior to the original scheduled test date or the revised test date, whichever is earlier. (40 CFR75.61(a)(1)(ii))
3) Repeat of testing without notice. Notwithstanding the above notice requirements, the owner or operator may elect to repeat a certification or recertification test immediately, without advance notification, whenever the owner or operator has determined during the certification or recertification testing that a test was failed or must be aborted, or that a second test is necessary in order to attain a reduced relative accuracy test frequency. (40 CFR75.61(a)(1)(iii))
stack or flue gas desulfurization system, of the planned date when a new stack or flue gas desulfurization system will be completed and emissions will first exit to the atmosphere. (40 CFR75.61(a)(2))
1) Notification of the planned date shall be submitted not later than 45 days prior to the date the unit commences commercial operation or becomes affected, or not later than 45 days prior to the date when a new stack or flue gas desulfurization system exhausts emissions to the atmosphere. (40 CFR75.61(a)(2)(i))
2) If the date when the unit commences commercial operation or becomes affected, or the date when the new stack or flue gas desulfurization system exhausts emissions to the atmosphere, whichever is applicable, changes from the planned date, a notification of the actual date shall be submitted not later than 7 days following: The date the unit commences commercial operation or becomes affected, or the date when a new stack or flue gas desulfurization system exhausts emissions to the atmosphere. (40 CFR75.61(a)(2)(ii))
1) For planned unit shutdowns (e.g., extended maintenance outages), written notification of the planned shutdown date shall be provided at least 21 days prior to the applicable compliance date, and written notification of the planned date of recommencement of commercial operation shall be provided at least 21 days in advance of unit restart. If the actual shutdown date or the actual date of recommencement of commercial operation differs from the planned date, written notice of the actual date shall be submitted no later than 7 days following the actual date of shutdown or of recommencement of commercial operation, as applicable; (40 CFR75.61(a)(3)(i))
2) For unplanned unit shutdowns (e.g., forced outages), written notification of the actual shutdown date shall be provided no more than 7 days after the shutdown, and written notification of the planned date of recommencement of commercial operation shall be provided at least 21 days in advance of unit restart. If the actual
date of recommencement of commercial operation differs from the expected date, written notice of the actual date shall be submitted no later than 7 days following the actual date of recommencement of commercial operation. (40 CFR75.61(a)(3)(ii))
1) Written notification under paragraph (a) (5) of 40 CFR 75.61 may be provided either by mail or by facsimile. In addition, written notification may be provided by electronic mail, provided that the respective State agency or office of EPA agrees that this is an acceptable form of notification. (40 CFR75.61(a)(5)(i))
2) Notwithstanding the notice requirements under paragraph (a)(5) of 40 CFR 75.61, the owner or operator may elect to repeat a periodic relative accuracy test, appendix E restest, or low mass emissions unit retest immediately, without additional notification whenever the owner or operator has determined that a test was failed, or that a second test is necessary in order to attain a reduced relative accuracy test frequency. (40 CFR75.61(a)(5)(ii))
1) Electronic. Using the format specified in paragraph (c) of 40 CFR 75.62, the designated representative for an affected unit shall submit a complete, electronic, up-to-date monitoring plan file (except for hardcopy portions identified in paragraph (a)(2) of 40 CFR 75.62) to the Administrator as follows: no later than 21 days prior to the initial certification tests; at the time of each certification or recertification application submission; and (prior to or concurrent with) the submittal of the electronic quarterly report for a reporting quarter where an update of the electronic monitoring plan information is required, either under 40 CFR 75.53(b) or elsewhere in this part. (40 CFR 75.62(a)(1))
2) Hardcopy. The designated representative shall submit all of the hardcopy information required under 40 CFR 75.53 to the appropriate EPA Regional Office and the appropriate State and/or local air pollution control agency prior to initial certification. Thereafter, the designated representative shall submit hardcopy information only if that portion of the monitoring plan is revised. The designated representative shall submit the required hardcopy information as follows: no later than 21 days prior to the initial certification test; with any certification or recertification application, if a hardcopy monitoring plan change is associated with the certification or recertification event; and within 30 days of any other event with which a hardcopy monitoring plan change is associated, pursuant to 40 CFR 75.53(b). Electronic submittal of all monitoring plan information, including hardcopy portions, is permissible provided that a paper copy of the hardcopy portions can be furnished upon request. (40 CFR 75.62(a)(2))
1) General provisions (40 CFR 75.53(a))
(a) On and after January 1, 2009, the owner or operator shall meet the requirements of paragraphs (a), (b), (g), and (h) of
40 CFR 75.53 only. In addition, the provisions in paragraphs (g) and (h) of 40 CFR 75.53 that support a regulatory option provided in another section of this part must be followed if the regulatory option is used prior to January 1, 2009. (40 CFR 75.53(a)(1))
(b) The owner or operator of an affected unit shall prepare and maintain a monitoring plan. Except as provided in paragraphs (f) or (h) of 40 CFR 75.53 (as applicable), a monitoring plan shall contain sufficient information on the continuous emission or opacity monitoring systems, excepted methodology under 40 CFR 75.19 (Optional SO2, NOx, and CO2 emissions calculation for low mass emissions units), or excepted monitoring systems under appendix D or E to this part and the use of data derived from these systems to demonstrate that all unit SO2 emissions, NOX emissions, CO2 emissions, and opacity are monitored and reported. (40 CFR 75.53(a)(2))
2) Whenever the owner or operator makes a replacement, modification, or change in the certified CEMS, continuous opacity monitoring system, excepted methodology under 40 CFR 75.19, excepted monitoring system under appendix D or E to this part, or alternative monitoring system under subpart E of this part, including a change in the automated data acquisition and handling system or in the flue gas handling system, that affects information reported in the monitoring plan (e.g., a change to a serial number for a component of a monitoring system), then the owner or operator shall update the monitoring plan, by the applicable deadline specified in 40 CFR 75.62 (Monitoring plan submittals) or elsewhere in this part. (40 CFR 75.53(b))
3) Contents of the monitoring plan (40 CFR 75.53(g))
The requirements of paragraphs (g) and (h) of this section shall be met on and after January 1, 2009. Notwithstanding this requirement, the provisions of paragraphs (g) and (h) of 40 CFR
75.53 may be implemented prior to January 1, 2009, as follows. Each monitoring plan shall contain the information in paragraph (g)(1) of 40 CFR 75.53 in electronic format and the information in paragraph (g)(2) of 40 CFR 75.53 in hardcopy format. Electronic storage of all monitoring plan information, including the hardcopy portions, is permissible provided that a paper copy of the information can be furnished upon request for audit purposes.
(a) Electronic (40 CFR 75.53(g)(1))
(i) The facility ORISPL number developed by the Department of Energy and used in the National Allowance Data Base (or equivalent facility ID number assigned by EPA, if the facility does not have an ORISPL number). Also provide the
following information for each unit and (as applicable) for each common stacks and/or pipe, and each multiple stack and/or pipe involved in the monitoring plan: (40 CFR 75.53(g)(1)(i))
(A) A representation of the exhaust configuration for the units in the monitoring plan. On and after April 27, 2011, provide the activation date and deactivation date (if applicable) of the configuration. Provide the ID number of each unit and assign a unique ID number to each common stack, common pipe multiple stack and/or multiple pipe associated with the unit(s) represented in the monitoring plan. For common and multiple stacks and/or pipes, provide the activation date and deactivation date (if applicable) of each stack and/or pipe; (40 CFR 75.53(g)(1)(i)(A))
(B) Identification of the monitoring system location(s) (e.g., at the unit-level, on the common stack, at each multiple stack, etc.). Provide an indicator (“flag”) if the monitoring location is at a bypass stack or in the ductwork (breeching); (40 CFR 75.53(g)(1)(i)(B))
(C) The stack exit height (ft) above ground level and ground level elevation above sea level, and the inside cross-sectional area (ft2) at the flue exit and at the flow monitoring location (for units with flow monitors, only). Also use appropriate codes to indicate the material(s) of construction and the shape(s) of the stack or duct cross-section(s) at the flue exit and (if applicable) at the flow monitor location. On and after April 27, 2011, provide the activation date and deactivation date (if applicable) for the information in this paragraph (g)(1)(i)(C); (40 CFR 75.53(g)(1)(i)(C))
(D) The type(s) of fuel(s) fired by each unit. Indicate the start and (if applicable) end date of combustion for each type of fuel, and
whether the fuel is the primary, secondary, emergency, or startup fuel; (40 CFR 75.53(g)(1)(i)(D))
(E) The type(s) of emission controls that are used to reduce SO2, NOX, and particulate emissions from each unit. Also provide the installation date, optimization date, and retirement date (if applicable) of the emission controls, and indicate whether the controls are an original installation; (40 CFR 75.53(g)(1)(i)(E))
(F) Maximum hourly heat input capacity of each unit. On and after April 27, 2011, provide the activation date and deactivation date (if applicable) for this parameter; and (40 CFR 75.53(g)(1)(i)(F))
(G) A non-load based unit indicator (if applicable) for units that do not produce electrical or thermal output. (40 CFR 75.53(g)(1)(i)(G))
(ii) For each monitored parameter (e.g., SO2, NOX, flow, etc.) at each monitoring location, specify the monitoring methodology and the missing data approach for the parameter. If the unmonitored bypass stack approach is used for a particular parameter, indicate this by means of an appropriate code. Provide the activation date/hour, and deactivation date/hour (if applicable) for each monitoring methodology and each missing data approach. (40 CFR 75.53(g)(1)(ii))
(iii) For each required continuous emission monitoring system, each fuel flowmeter system, and each continuous opacity monitoring system, identify and describe the major monitoring components in the monitoring system (e.g., gas analyzer, flow monitor, opacity monitor, moisture sensor, fuel flowmeter, DAHS software, etc.). Other important components in the system (e.g., sample probe, PLC, data logger, etc.) may also be represented in the monitoring plan, if necessary. Provide the following specific information about each component and monitoring
system: (40 CFR 75.53(g)(1)(iii))
(A) For each required monitoring system: (40 CFR 75.53(g)(1)(iii)(A))
(I) Assign a unique, 3-character alphanumeric identification code to the system; (40 CFR 75.53(g)(1)(iii)(A)(1))
(II) Indicate the parameter monitored by the system; (40 CFR 75.53(g)(1)(iii)(A)(2))
(III) Designate the system as a primary, redundant backup, non-redundant backup, data backup, or reference method backup system, as provided in 40 CFR 75.10(e) (Optional backup monitor requirements); and (40 CFR 75.53(g)(1)(iii)(A)(3))
(IV) Indicate the system activation date/hour and deactivation date/hour (as applicable). (40 CFR 75.53(g)(1)(iii)(A)(4))
(B) For each component of each monitoring system represented in the monitoring plan: (40 CFR 75.53(g)(1)(iii)(B))
(I) Assign a unique, 3-character alphanumeric identification code to the component; (40 CFR 75.53(g)(1)(iii)(B)(1))
(II) Indicate the manufacturer, model and serial number; (40 CFR 75.53(g)(1)(iii)(B)(3))
(III) Designate the component type; (40 CFR 75.53(g)(1)(iii)(B)(3))
(IV) For dual-span applications, indicate whether the analyzer component ID represents a high measurement scale,
a low scale, or a dual range; (40 CFR 75.53(g)(1)(iii)(B)(4))
(V) For gas analyzers, indicate the moisture basis of measurement; (40 CFR 75.53(g)(1)(iii)(B)(5))
(VI) Indicate the method of sample acquisition or operation, (e.g., extractive pollutant concentration monitor or thermal flow monitor); and (40 CFR 75.53(g)(1)(iii)(B)(6))
(VII) Indicate the component activation date/hour and deactivation date/hour (as applicable). (40 CFR 75.53(g)(1)(iii)(B)(7))
(iv) Explicit formulas, using the component and system identification codes for the primary monitoring system, and containing all constants and factors required to derive the required mass emissions, emission rates, heat input rates, etc. from the hourly data recorded by the monitoring systems. Formulas using the system and component ID codes for backup monitoring systems are required only if different formulas for the same parameter are used for the primary and backup monitoring systems (e.g., if the primary system measures pollutant concentration on a different moisture basis from the backup system). Provide the equation number or other appropriate code for each emissions formula (e.g., use code F–1 if Equation F–1 in appendix F to this part is used to calculate SO2 mass emissions). Also identify each emissions formula with a unique three character alphanumeric code. The formula effective start date/hour and inactivation date/hour (as applicable) shall be included for each formula. The owner or operator of a unit for which the optional low mass emissions excepted methodology in 40 CFR 75.19 is being used is not required to report such formulas. (40 CFR 75.53(g)(1)(iv))
(v) For each parameter monitored with CEMS, provide the following information: (40 CFR 75.53(g)(1)(v))
(A) Measurement scale (high or low); (40 CFR 75.53(g)(1)(v)(A))
(B) Maximum potential value (and method of calculation). If NOX emission rate in lb/mmBtu is monitored, calculate and provide the maximum potential NOX emission rate in addition to the maximum potential NOX concentration; (40 CFR 75.53(g)(1)(v)(B))
(C) Maximum expected value (if applicable) and method of calculation; (40 CFR 75.53(g)(1)(v)(C))
(D) Span value(s) and full-scale measurement range(s); (40 CFR 75.53(g)(1)(v)(D))
(E) Daily calibration units of measure; (40 CFR 75.53(g)(1)(v)(E))
(F) Effective date/hour, and (if applicable) inactivation date/hour of each span value. On and after April 27, 2011, provide the activation date and deactivation date (if applicable) for the measurement scale and dual span information in paragraphs (g)(1)(v)(A), (g)(1)(v)(G), and (g)(1)(v)(H) of 40 CFR 75.53; (40 CFR 75.53(g)(1)(v)(F))
(G) An indication of whether dual spans are required. If two span values are required, then, on and after April 27, 2011, indicate whether an autoranging analyzer is used to represent the two measurement scales; and (40 CFR 75.53(g)(1)(v)(G))
(H) The default high range value (if applicable) and the maximum allowable low-range value for this option. (40 CFR 75.53(g)(1)(v)(H))
(vi) If the monitoring system or excepted methodology provides for the use of a constant, assumed, or default value for a parameter under specific
circumstances, then include the following information for each such value for each parameter: (40 CFR 75.53(g)(1)(vi))
(A) Identification of the parameter; (40 CFR 75.53(g)(1)(vi)(A))
(B) Default, maximum, minimum, or constant value, and units of measure for the value; (40 CFR 75.53(g)(1)(vi)(B))
(C) Purpose of the value; (40 CFR 75.53(g)(1)(vi)(C))
(D) Indicator of use, i.e., during controlled hours, uncontrolled hours, or all operating hours; (40 CFR 75.53(g)(1)(vi)(D))
(E) Type of fuel; (40 CFR 75.53(g)(1)(vi)(E))
(F) Source of the value; (40 CFR 75.53(g)(1)(vi)(F))
(G) Value effective date and hour; (40 CFR 75.53(g)(1)(vi)(G))
(H) Date and hour that the value is no longer effective (if applicable); (40 CFR 75.53(g)(1)(vi)(H))
(I) For units using the excepted methodology under 40 CFR 75.19, the applicable SO2 emission factor; and (40 CFR 75.53(g)(1)(vi)(I))
(J) On and after April 27, 2011, group identification code. (40 CFR 75.53(g)(1)(vi)(J))
(vii) Unless otherwise specified in section 6.5.2.1 of appendix A to this part, for each unit or common stacks on which hardware CEMS are installed: (40 CFR 75.53(g)(1)(vii))
(A) Maximum hourly gross load (in MW, rounded to the nearest MW, or steam load in
1000 lb/hr (i.e., klb/hr), rounded to the nearest klb/hr, or thermal output in mmBtu/hr, rounded to the nearest mmBtu/hr), for units that produce electrical or thermal output; (40 CFR 75.53(g)(1)(vii)(A))
(B) The upper and lower boundaries of the range of operation (as defined in section 6.5.2.1 of appendix A to this part), expressed in megawatts, thousands of lb/hr of steam, mmBtu/hr of thermal output, or ft/sec (as applicable); (40 CFR 75.53(g)(1)(vii)(B))
(C) Except for peaking units, identify the most frequently and second most frequently used load (or operating) levels (i.e., low, mid, or high) in accordance with section 6.5.2.1 of appendix A to this part, expressed in megawatts, thousands of lb/hr of steam, mmBtu/hr of thermal output, or ft/sec (as applicable); (40 CFR 75.53(g)(1)(vii)(C))
(D) Except for peaking units, an indicator of whether the second most frequently used load (or operating) level is designated as normal in section 6.5.2.1 of appendix A to this part; (40 CFR 75.53(g)(1)(vii)(D))
(E) The date of the data analysis used to determine the normal load (or operating) level(s) and the two most frequently-used load (or operating) levels (as applicable); and (40 CFR 75.53(g)(1)(vii)(E))
(F) Activation and deactivation dates and hours, when the maximum hourly gross load, boundaries of the range of operation, normal load (or operating) level(s) or two most frequently-used load (or operating) levels change and are updated. (40 CFR 75.53(g)(1)(vii)(F))
(b) Hardcopy (40 CFR 75.53(g)(2))
(i) Information, including (as applicable):
Identification of the test strategy; protocol for the relative accuracy test audit; other relevant test information; calibration gas levels (percent of span) for the calibration error test and linearity check; calculations for determining maximum potential concentration, maximum expected concentration (if applicable), maximum potential flow rate, maximum potential NOX emission rate, and span; and apportionment strategies under 40 CFR 75.10 through 75.18. (40 CFR 75.53(g)(2)(i))
(ii) Description of site locations for each monitoring component in the continuous emission or opacity monitoring systems, including schematic diagrams and engineering drawings specified in paragraphs (e)(2)(iv) and (e)(2)(v) of 40 CFR 75.53 and any other documentation that demonstrates each monitor location meets the appropriate siting criteria. (40 CFR 75.53(g)(2)(ii))
(iii) A data flow diagram denoting the complete information handling path from output signals of CEMS components to final reports. (40 CFR 75.53(g)(2)(iii))
(iv) For units monitored by a continuous emission or opacity monitoring system, a schematic diagram identifying entire gas handling system from boiler to stack for all affected units, using identification numbers for units, monitoring systems and components, and stacks corresponding to the identification numbers provided in paragraphs (g)(1)(i) and (g)(1)(iii) of 40 CFR 75.53. The schematic diagram must depict stack height and the height of any monitor locations. Comprehensive and/or separate schematic diagrams shall be used to describe groups of units using a common stack. (40 CFR 75.53(g)(2)(iv))
(v) For units monitored by a continuous emission or opacity monitoring system, stack and duct engineering diagrams showing the dimensions and location of fans, turning vanes, air preheaters, monitor components, probes, reference method sampling ports, and other equipment that affects the monitoring system location, performance, or quality
control checks. (40 CFR 75.53(g)(2)(v))
The designated representative for an affected unit or a combustion source shall submit applications and reports as follows:
1) Recertifications and diagnostic testing (40 CFR 75.63(a)(2))
(a) Within 45 days after completing all recertification tests under 40 CFR 75.20(b), submit to the Administrator the electronic information required by paragraph (b)(1) of 40 CFR 75.63. Except for subpart E applications for alternative monitoring systems or unless specifically requested by the Administrator, do not submit a hardcopy of the test data and results to the Administrator. (40 CFR 75.63(a)(2)(i))
(b) Within 45 days after completing all recertification tests under 40 CFR 75.20(b), submit the hardcopy information required by paragraph (b)(2) of 40 CFR 75.63 to the applicable EPA Regional Office and the appropriate State and/or local air pollution control agency. The applicable EPA Regional Office or appropriate State or local air pollution control agency may waive the requirement to provide hardcopy recertification test and data results. The applicable EPA Regional Office or the appropriate State or local air pollution control agency may also discontinue the waiver and reinstate the requirement of this paragraph to provide a hardcopy report of the recertification test data and results. (40 CFR 75.63(a)(2)(ii))
(c) Notwithstanding the requirements of paragraphs (a)(2)(i) and (a)(2)(ii) of 40 CFR 75.63, for an event for which the Administrator determines that only diagnostic tests (see 40 CFR 75.20(b)) are required rather than recertification testing, no hardcopy submittal is required; however, the results of all diagnostic test(s) shall be submitted prior to or concurrent with the electronic quarterly report required under 40 CFR 75.64. Notwithstanding the requirement of 40 CFR 75.59(e), for DAHS (missing data and formula) verifications, no hardcopy submittal is required; the owner or operator shall keep these test results on-site in a format suitable for inspection. (40 CFR 75.63(a)(2)(iii))
Each application for recertification shall contain the following information, as applicable:
1) Electronic (75.63(b)(1))
(a) A complete, up-to-date version of the electronic portion of the monitoring plan, according to 40 CFR 75.53(e) and (f), in the format specified by the Administrator. (75.63(b)(1)(i))
(b) The results of the test(s) required by 40 CFR 75.20, including the type of test conducted, testing date, information required by 40 CFR 75.59 (Certification, quality assurance, and quality control record provisions), and the results of any failed tests that affect data validation. (75.63(b)(1)(ii))
2) Hardcopy (75.63(b)(2))
(a) Any changed portions of the hardcopy monitoring plan information required under 40 CFR 75.53(e) and (f). Electronic submittal of all monitoring plan information, including the hardcopy portions, is permissible, provided that a paper copy can be furnished upon request. (75.63(b)(2)(i))
(b) The results of the test(s) required by 40 CFR 75.20, including the type of test conducted, testing date, information required by 40 CFR 75.59(a)(9) (See Condition S1.a.ii.), and the results of any failed tests that affect data validation. (75.63(b)(2)(ii))
(c) Designated representative signature certifying the accuracy of the submission. (75.63(b)(2)(ii))
The electronic portion of each certification or recertification application shall be submitted in a format to be specified by the Administrator. The hardcopy test results shall be submitted in a format suitable for review and shall include the information in 40 CFR 75.59(a)(9) (See Condition S1.a.ii.)
The designated representative for an affected unit shall electronically report the data and information in paragraphs (a) and (c) of 40 CFR 75.64 to the Administrator quarterly, beginning with the data from the earlier of the calendar quarter corresponding to the date of provisional certification or the calendar quarter corresponding to the relevant deadline for initial certification in 40 CFR 75.4(a), and (c). The initial quarterly report shall contain hourly data beginning with the hour of provisional certification or the hour corresponding to the relevant certification deadline, whichever is earlier. For any provisionally-certified monitoring system, 40 CFR 75.20(a)(3) shall apply for initial certifications, and 40 CFR 75.20(b)(5) shall apply for recertifications. Each electronic report must be submitted to the Administrator within 30 days following the end of each calendar quarter. On and after January 1, 2009, the owner or operator shall meet the requirements of paragraphs (a)(3) through (a)(15) of 40 CFR 75.64 only. Each electronic report shall also include the date of report generation. (The electronic quarterly reports are submitted to EPA)
1) Facility identification information, including: (40 CFR 75.64(a)(3))
(a) Facility/ORISPL number; (40 CFR 75.64(a)(3)(i))
(b) Calendar quarter and year for the data contained in the report; and (40 CFR 75.64(a)(3)(ii))
(c) Version of the electronic data reporting format used for the report. (40 CFR 75.64(a)(3)(iii))
2) In accordance with 40 CFR 75.62(a)(1), if any monitoring plan information required in 40 CFR 75.53 (monitoring plan requirements) requires an update, either under 40 CFR 75.53(b) or elsewhere in this part, submission of the electronic monitoring plan update shall be completed prior to or concurrent with the submittal of the quarterly electronic data report for the appropriate quarter in which the update is required. (40 CFR 75.64(a)(4))
3) The daily calibration error test and daily interference check information required in 75.59(a)(1) and (a)(2) must always be included in the electronic quarterly emissions report. All other certification, quality assurance, and quality control information in
75.59 that is not excluded from electronic reporting under paragraph (a)(2) or (a)(7) of 40 CFR 75.64 shall be submitted separately, either prior to or concurrent with the submittal of the relevant electronic quarterly emissions report. However, reporting of the information in 75.59(a)(9)(x) is not required until September
26, 2011, and reporting of the information in 75.59(a)(15), (b)(6), and (d)(4) is not required until March 27, 2012. (40 CFR 75.64(a)(5))
4) The information and hourly data required in 40 CFR 75.57 through
75.59 (General recordkeeping provisions; General recordkeeping for specific situations; Certification, quality assurance, and quality control record provisions), and daily calibration error test data, daily interference check, and off-line calibration demonstration information required in 40 CFR 75.59(a)(1) and (2). (40 CFR 75.64(a)(6))
5) Notwithstanding the requirements of paragraphs (a)(4) through (a)(6) of 40 CFR 75.64, the following information is excluded from electronic reporting: (40 CFR 75.64(a)(7))
(a) Descriptions of adjustments, corrective action, and maintenance; (40 CFR 75.64(a)(7)(i))
(b) Information which is incompatible with electronic reporting (e.g., field data sheets, lab analyses, quality control plan); (40 CFR 75.64(a)(7)(ii))
(c) Opacity data listed in 40 CFR 75.57(f), and in 40 CFR 75.59(a)(8); (40 CFR 75.64(a)(7)(iii))
(d) For units with SO2 or NOX add-on emission controls that do not elect to use the approved site-specific parametric monitoring procedures for calculation of substitute data, the information in 40 CFR 75.58(b)(3); (40 CFR 75.64(a)(7)(iv))
(e) Information required by 40 CFR 75.57(h) concerning the causes of any missing data periods and the actions taken to cure such causes; (40 CFR 75.64(a)(7)(v))
(f) Hardcopy monitoring plan information required by 40 CFR
75.53 and hardcopy test data and results required by 40 CFR 75.59; (40 CFR 75.64(a)(7)(vi))
(g) Records of flow monitor and moisture monitoring system polynomial equations, coefficients, or “K” factors required by 40 CFR 75.59(a)(5)(vi) or 40 CFR 75.59(a)(5)(vii); (40 CFR 75.64(a)(7)(vii))
(h) Daily fuel sampling information required by 40 CFR 75.58(c)(3)(i) for units using assumed values under appendix D of this part; (40 CFR 75.64(a)(7)(viii))
(i) Information required by 40 CFR 75.59(b)(1)(vi), (vii), (viii), (ix), and (xiii), and (b)(2)(iii) and (iv) concerning fuel flowmeter accuracy tests and transmitter/transducer accuracy tests; (40 CFR 75.64(a)(7)(ix))
(j) Stratification test results required as part of the RATA supplementary records under 40 CFR 75.59(a)(7); (40 CFR 75.64(a)(7)(x))
(k) Data and results of RATAs that are aborted or invalidated due to problems with the reference method or operational problems with the unit and data and results of linearity checks that are aborted or invalidated due to problems unrelated to monitor performance; (40 CFR 75.64(a)(7)(xi))
(l) Supplementary RATA information required under 40 CFR 75.59(a)(7)(i) through 40 CFR 75.59(a)(7)(v) (supporting information for RATA), except that: (40 CFR 75.64(a)(7)(xii))
(i) The applicable data elements under 40 CFR 75.59(a)(7)(ii)(A) through (T) and under 40 CFR 75.59(a)(7)(iii)(A) through (M) (supporting information for RATA using Method 2) shall be reported for flow RATAs at circular or rectangular stacks (or ducts) in which angular compensation for yaw and/or pitch angles is used (i.e., Method 2F or 2G in appendices A–1 and A–2 to part 60 of this chapter), with or without wall effects adjustments; (40 CFR 75.64(a)(7)(xii)(A))
(ii) The applicable data elements under 40 CFR 75.59(a)(7)(ii)(A) through (T) and under 40 CFR 75.59(a)(7)(iii)(A) through (M) (supporting information for RATA using Method 2) shall be reported for any flow RATA run at a circular stack in which Method 2 in appendices A–1 and A–2 to part 60 of this chapter is used and a wall effects adjustment factor is determined by direct measurement; (40 CFR 75.64(a)(7)(xii)(B))
(iii) The data under 40 CFR 75.59(a)(7)(ii)(T) (supporting information for RATA using Method 2)
shall be reported for all flow RATAs at circular stacks in which Method 2 in appendices A–1 and A–2 to part 60 of this chapter is used and a default wall effects adjustment factor is applied. (40 CFR 75.64(a)(7)(xii)(C))
6) Tons (rounded to the nearest tenth) of SO2 emitted during the quarter and cumulative SO2 emissions for the calendar year. (40 CFR 75.64(a)(8))
7) Average NOX emission rate (lb/mmBtu, rounded to the nearest thousandth) during the quarter and cumulative NOX emission rate for the calendar year. (40 CFR 75.64(a)(9))
8) Tons of CO2 emitted during quarter and cumulative CO2 emissions for calendar year. (40 CFR 75.64(a)(10))
9) Total heat input (mmBtu) for quarter and cumulative heat input for calendar year. (40 CFR 75.64(a)(11))
10) Unit or stack or common pipe header operating hours for quarter and cumulative unit or stack or common pipe header operating hours for calendar year. (40 CFR 75.64(a)(12))
The designated representative shall submit a certification in support of each quarterly emissions monitoring report based on reasonable inquiry of those persons with primary responsibility for ensuring that all of the unit’s emissions are correctly and fully monitored. The certification shall indicate whether the monitoring data submitted were recorded in accordance with the applicable requirements of this part including the quality control and quality assurance procedures and specifications of this part and its appendices, and any such requirements, procedures and specifications of an applicable excepted or approved alternative monitoring method. For a unit with add-on emission controls, the designated representative shall also include a certification, for all hours where data are substituted following the provisions of 40 CFR 75.34(a)(1) (missing data substitution procedures for units with add-on emission controls), that the add-on emission controls were operating within the range of parameters listed in the monitoring plan and that the substitute values recorded during the quarter do not systematically underestimate SO2 or NOX emissions, pursuant to 40 CFR 75.34 (Missing Data Substitution Procedure).
Beginning with the quarterly report for the first quarter of the year 2001, all quarterly reports shall be submitted to EPA by direct computer-to- computer electronic transfer via EPA-provided software, unless otherwise approved by the Administrator.
The owner or operator or designated representative shall report excess emissions of opacity recorded under 40 CFR 75.57(f) (opacity recordkeeping requirements) to the applicable State or local air pollution control agency.
Attachment E – Control Device Efficiencies and Determination Methods
Unit ID |
Control ID |
Description |
Control Efficiency |
Control Efficiency Determination Method2 |
U4 |
C1 |
ESP |
N/A |
CEMS used for compliance demo. |
C2 |
FGD |
N/A |
CEMS used for compliance demo. |
|
C7 |
dust collector |
90% |
Option 1. |
|
U5 |
C3 |
ESP |
N/A |
CEMS used for compliance demo. |
C4 |
FGD |
N/A |
CEMS used for compliance demo. |
|
C8 |
dust collector |
90% |
Option 1. |
|
U6 |
C5 |
ESP |
N/A |
CEMS used for compliance demo. |
C6 |
FGD |
N/A |
CEMS used for compliance demo. |
|
C9 |
dust collector |
90% |
Option 1. |
|
U7 |
C11 |
Baghouse |
95% |
Option 1 |
C12 |
Baghouse |
95% |
Option 1 |
|
C13 |
Baghouse |
95% |
Option 1 |
|
C14a |
Wet cyclone |
96% |
Option 2, received 8/19/2011 |
|
C14b |
HEPA filter |
95% |
Option 1 |
|
C15 |
Baghouse |
95% |
Option 1 |
|
C16 |
Baghouse |
95% |
Option 1 |
|
U8 |
C18 |
Baghouse |
95% |
Option 1. |
U14 |
C19 |
Scrubber |
85% |
Option 1. |
C20 |
Scrubber |
85% |
Option 1. |
|
C21 |
Scrubber |
85% |
Option 1. |
|
C22 |
Scrubber |
85% |
Option 1. |
|
U15 |
C23 |
Cata. Oxidizer |
50% |
Option 2 |
C24 |
Cata. Oxidizer |
50% |
Option 2 |
|
U19, U20 |
|
Watering |
70% |
Option 1 |
Note:
Option 1: Use District pre-approved control efficiency.
Option 2: Submit a guarantee with signature from the control device manufacture stating the control device efficiency.
Option 3: Perform stack test. See Note 3 for general testing requirements.
Plant-wide the owner or operator shall retest all control devices within ten (10) years since the most recent District accepted performance test or within 180 days after the effective date of the permit if no previous test has been performed. For equipment which has been tested but not within ten years prior to the effective date of this permit the Company may submit within 90 days of the effective date of this permit, contingent on approval by the District, a schedule which shall at a minimum propose testing for all affected equipment within this permit cycle. Thereafter the Company shall retest each affected device at least once every 10 years. Devices of adequately similar design and filter media may be represented by a common performance test contingent upon review and approval by the District of the testing protocol. In lieu of the control efficiency testing, unless required by a Federal Regulation, the owner or operator may submit a signature guarantee from the control device manufacture stating the control device efficiency.
The owner or operator shall construct all equipment in such a manner that the following testing requirements can be performed.
Louisville Metro Air Pollution Control District 850 Barret Avenue
Louisville, Kentucky 40204-1745
TITLE IV
PHASE II ACID RAIN PERMIT
Permit No.: 144-97-AR (R3) Plant ID: 0126
Effective Date: x/xx/2014 Expiration Date: x/xx/2019
Permission is hereby given by the Louisville Metro Air Pollution Control District to operate the process(es) and equipment described herein which are located at:
Louisville Gas & Electric Company Cane Run Generating Station
5252 Cane Run Road Louisville, KY 40232
Statutory and Regulatory Authorities: In accordance with KRS Chapter 77 and Titles IV and V of the Clean Air Act, the Air Pollution Control District of Jefferson County issues this permit pursuant to Regulations 2.16, 6.47, and 7.82.
Application No.: N/A Application Received: 12/13/1995 Permit Writer: Yiqiu Lin
Administratively Complete: 2/7/1996
Acid Rain Permit Revisions/Changes
Revision No. |
Issue Date |
Public Notice Date |
Type |
Attachment No./Page No. |
Description |
Initial |
12/17/1997 |
N/A |
Initial |
Entire Permit |
Initial Issuance |
R1 |
1/13/1999 |
N/A |
Significant |
Entire Permit |
Added language and SO2 allowances to the tables for each unit |
R2 |
08/30/2012 |
N/A |
Reissuance |
Entire Permit |
Reissuance of the permit |
R3 |
xx/xx/2014 |
08/30/2014 |
Renewal |
Entire Permit |
Renewal of the permit |
Acid Rain Permit Conditions
Unit U4: SO2 Allowances |
SO2 Allowances for Years 2008 – 2009 |
SO2 Allowances for Years 2010 and Beyond |
Table 2 of 40 CFR 73 |
4521* |
2726* |
Unit U4: NOx Requirements |
|
NOx Limit |
Pursuant to 40 CFR 76, the Kentucky Division for Air Quality approves a Phase II NOx Compliance Plan which includes a Phase II NOx Averaging Plan for Unit 4. This plan is effective for calendar year 2013 through 2017. Under the compliance plan, this unit’s annual average NOx emission rate for each year, determined in accordance with 40 CFR 75, shall not exceed the alternative contemporaneous emissions limitation (ACEL) of 0.46 lb/MMBtu in accordance with 40 CFR 76.11(d)(1)(i). If one or more of the units does not meet the requirement under 40 CFR 76.11(d)(1)(i), the owner or operator shall demonstrate that the actual Btu-weighted annual average emission rate for the units in the NOx Averaging Plan is less than or equal to the Btu-weighted annual average rate for the same units, in accordance with 40 CFR 76.11(d)(1)(ii).
In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions. |
* The number of allowances actually held by an affected source in a unit account may differ from the number allocated by U.S. EPA. Neither of the aforementioned conditions necessitates a revision to the unit SO2 allowance allocations identified in this permit (See 40 CFR 72.84). The number of allowances allocated to Phase II affected units by US EPA may change under 40 CFR Part 73.
Unit U5: SO2 Allowances |
SO2 Allowances for Years 2008 – 2009 (tons) |
SO2 Allowances for Years 2010 and Beyond (tons) |
Table 2 of 40 CFR 73 |
4,340* |
4,330* |
Unit U5: NOx Requirements |
|
NOx Limit |
Pursuant to 40 CFR 76, the Kentucky Division for Air Quality approves a Phase II NOx Compliance Plan which includes a Phase II NOx Averaging Plan for Unit 5. This plan is effective for calendar year 2013 through 2017. Under the compliance plan, this unit’s annual average NOx emission rate for each year, determined in accordance with 40 CFR 75, shall not exceed the alternative contemporaneous emissions limitation (ACEL) of 0.46 lb/MMBtu in accordance with 40 CFR 76.11(d)(1)(i). If one or more of the units does not meet the requirement under 40 CFR 76.11(d)(1)(i), the owner or operator shall demonstrate that the actual Btu-weighted annual average emission rate for the units in the NOx Averaging Plan is less than or equal to the Btu-weighted annual average rate for the same units, in accordance with 40 CFR 76.11(d)(1)(ii).
In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions. |
* The number of allowances actually held by an affected source in a unit account may differ from the number allocated by U.S. EPA. Neither of the aforementioned conditions necessitates a revision to the unit SO2 allowance allocations identified in this permit (See 40 CFR 72.84). The number of allowances allocated to Phase II affected units by US EPA may change under 40 CFR part 73.
Unit U6: SO2 Allowances |
SO2 Allowances for Years 2008 – 2009 (tons) |
SO2 Allowances for Years 2010 and Beyond (tons) |
Table 2 of 40 CFR 73 |
5,498* |
5,436* |
Unit U6: NOx Requirements |
|
NOx Limit |
Pursuant to 40 CFR 76, the Kentucky Division for Air Quality approves a Phase II NOx Compliance Plan which includes a Phase II NOx Averaging Plan for Unit 6. This plan is effective for calendar year 2013 through 2017. Under the compliance plan, this unit’s annual average NOx emission rate for each year, determined in accordance with 40 CFR 75, shall not exceed the alternative contemporaneous emissions limitation (ACEL) of 0.40 lb/MMBtu in accordance with 40 CFR 76.11(d)(1)(i). If one or more of the units does not meet the requirement under 40 CFR 76.11(d)(1)(i), the owner or operator shall demonstrate that the actual Btu-weighted annual average emission rate for the units in the NOx Averaging Plan is less than or equal to the Btu-weighted annual average rate for the same units, in accordance with 40 CFR 76.11(d)(1)(ii).
In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions. |
* The number of allowances actually held by an affected source in a unit account may differ from the number allocated by U.S. EPA. Neither of the aforementioned conditions necessitates a revision to the unit SO2 allowance allocations identified in this permit (See 40 CFR 72.84). The number of allowances allocated to Phase II affected units by US EPA may change under 40 CFR part 73.
Unit U15: SO2 Allowances |
SO2 Allowances for Years 2008 – 2009 (tons) |
SO2 Allowances for Years 2010 and Beyond (tons) |
Table 2 of 40 CFR 73 |
0* |
0* |
Unit U15: NOx Requirements |
|
NOx Limit |
This emission unit currently does not have applicable NOx limits set by 40 CFR 76. |
* For newly constructed emission unit, there are no SO2 allowances per EPA Acid Rain Program. A minimum balance of “0” SO2 allowances shall be maintained in the account. If there are not enough SO2 allowances to cover the SO2 produced by U15 for the calendar year, SO2 allowances shall be transferred to the U15 account by the allowance transfer deadline1 by March 1 of the following calendar year, to maintain a minimum balance of “0” SO2 allowances.
Allowable transfer deadline by definition is midnight of March 1 and is the deadline by which allowances may be submitted for recordation in an affected source’s compliance account for the purposes of meeting the source’s Acid Rain emissions limitation requirements for the sulfur dioxide for the previous calendar year.(CFR 72 Subpart A
§72.2, CFR 73 Subpart B §73.20(d)(2))
The number of allowances actually held by an affected source in a unit account may differ from the number allocated by U.S. EPA. Neither of the aforementioned conditions necessitates a revision to the unit SO2 allowance allocations identified in this permit (See 40 CFR 72.84). The number of allowances allocated to Phase II affected units by US EPA may change under 40 CFR Part 73.
Comments, Notes, and Justifications:
(1) Affected emission units are two (2) existing dry bottom wall-fired boilers, one (1) existing tangentially fired boiler, and one (1) new natural gas-fired combined cycle (NGCC) electricity generating unit.
(2) A revised Phase II NOx Compliance Plan was received on June 27, 2008, including the existing emission unit.
(3) All previously issued Acid Rain permits are hereby null and void.
Permit Application:
The Louisville Gas & Electric Company submitted Phase II Permit Application for the Mill Creek Generating Station, dated December 7, 1995, and signed by Chris Hermann. The owners and operators of Louisville Gas and Electric Company must comply with the standard requirements and special provisions set forth in the application.
NOx Compliance Plan:
Pursuant to 40 CFR 76, the Kentucky Division for Air Quality approves a Phase II NOx Compliance Plan for Louisville Gas & Electric Company. The owners and operators of Louisville Gas & Electric Company must comply with the alternative contemporaneous emissions limitation for NOx 0.40 lb/MMBtu for tagentially fired boilers and 0.46 lb/MMBtu for dry bottom wall-fired boilers. Each affected unit in an approved averaging plan is in compliance with the Acid Rain emission limitation for NOx under the plan only if the requirements under 40 CFR 76.11(d)(1) are met.
Copyright Soilworks, LLC 2003-. All Rights Reserved. Soilworks®, Soiltac®, Gorilla-Snot®, and Durasoil®are registered trademarks of Soilworks, LCC.
Copyright Soilworks, LLC 2003-. All Rights Reserved. Soilworks®, Soiltac®, Gorilla-Snot®, and Durasoil® are registered trademarks of Soilworks, LCC.