Permit #53418 1 of 131 August 15, 2012 

Tucson Electric Power-SGS 

AIR QUALITY CLASS I PERMIT 

COMPANY: Tucson Electric Power Company 

FACILITY: Springerville Generating Station 

PERMIT #: 53418 

DATE ISSUED: September 4, 2012 

EXPIRY DATE: September 4, 2017 

SUMMARY

This Class I, Title V operating permit renewal is issued to Tucson Electric Power Company 

(TEP), the Permittee, for the continued operation of its Springerville Generating Station (SGS), 

located in Apache County, approximately 15 miles North of Springerville, Arizona. The area is 

either unclassified or is classified as being in attainment for all criteria pollutants. This is a 

renewal of Operating Permit #32008. 

The Springerville Generating Station is classified as a Class I, Major Source. The potential 

emission rates of the particulate matter with an aerodynamic diameter less than 10 microns 

(PM10), sulfur dioxide (SO2), nitrogen oxides (NOx), carbon monoxides (CO), volatile organic 

compounds (VOCs), and sulfuric acid mist are greater than 100 tons per year. In addition, SGS 

has potential emission rates of hazardous air pollutants in excess of 25 tons per year in total, and 

in excess of the major source threshold of 10 tons per year for one or more of the cyanide 

compounds, hydrogen chloride, and hydrogen fluoride. SGS is also subject to the Acid Rain 

Program of the Clean Air Act. 

An Approval to Construct for two coal-fired steam electric generating units was issued by the 

Environmental Protection Agency (EPA) on December 21, 1977, to the facility. These two 

pulverized coal-fired, steam generating units are rated to produce a combined output of 

approximately 760 net megawatts. Each unit typically operates 24 hours per day, seven days per 

week, and 365 days per year. Both units normally burn coal. Units 1 & 2 have a capacity to 

process 5,272,000 tons of coal per year. Units 1 and 2 are also permitted to burn dual fuel (cofiring of fuel oil and coal for Units 1 & 2, and co-firing of used oil and coal for Unit 1). 

Baghouses are utilized to control particulate matter emissions. Spray dry absorbers are used to 

control SO2. Low NOx burners, overfire air ports, and good operating practices control NOx

emissions. 

A significant permit revision for the construction of two (2) new pulverized coal-fired steam 

electric generating units, “Unit 3” and “Unit 4” was issued on April 29, 2002. Unit 3 commenced 

operation in the year 2006 and Unit 4 commenced operation on December 17, 2009. Unit 3 and 

Unit 4 are primarily coal-fired. Each of these units is rated to produce approximately 420 net 

megawatts. Both Unit 3 and Unit 4 typically operate 24 hours per day, seven days per week, and 
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365 days per year. Each of the two units utilize baghouses to capture particulate matter 

emissions; spray dry absorbers to control emissions of sulfur dioxide and other acid gases; and 

low-NOx burners and selective catalytic reduction (SCR) units to control nitrogen oxides 

emissions. The major modification was subject to Prevention of Significant Deterioration (PSD) 

review for, PM, PM10, CO, VOC, and fluorides. The applicant voluntarily accepted emission caps 

on facility-wide emissions of SO2, NOx, and sulfuric acid mist. Thus, PSD review was not 

required for these pollutants. 

In addition to the pulverized coal-fired steam electric generating units, SGS includes various 

ancillary facilities such as an oil-fired auxiliary boiler, a coal preparation plant, coal storage piles, 

lime storage and handling facilities, two mechanical-draft wet cooling towers. As part of the 

major modification to add Unit 3 and Unit 4, two new mechanical-draft wet cooling towers using 

high-efficiency drift eliminators, new lime storage and handling facilities using enclosures and 

fabric filters, and new anhydrous ammonia storage tanks were installed. The coal preparation 

plant and coal storage was expanded to accommodate the two new Units 3 and 4. During 

construction of Unit 4 a carbon injection system for mercury removal was also installed. 

This permit is issued in accordance with Title V of the Clean Air Act, and Title 49, Chapter 3 of 

the Arizona Revised Statutes. All definitions, terms, and conditions used in this permit conform 

to those in the Arizona Administrative Code R18-2-101 et. seq. (A.A.C) and 40 Code of Federal 

Regulations (CFR), except as otherwise defined in this permit. Unless noted otherwise, 

references cited in the permit conditions refer to the A.A.C. All material permit conditions have 

been identified within the permit by a double underline. All terms and conditions of this permit 

are enforceable by the Administrator of the United States Environmental Protection Agency (U.S. 

EPA) except for those terms and conditions that are specifically designated as “State 

Requirements.” 
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TABLE OF CONTENTS 

ATTACHMENT “A” ..................................................................................................................................5

I. PERMIT EXPIRATION AND RENEWAL ...................................................................................5 

II. COMPLIANCE WITH PERMIT CONDITIONS............................................................................5 

III. PERMIT REVISION, REOPENING, REVOCATION ANDREISSUANCE, OR 

TERMINATION FOR CAUSE ......................................................................................................5 

IV. POSTING OF PERMIT ...................................................................................................................6 

V. FEE PAYMENT...............................................................................................................................6 

VI. ANNUAL EMISSION INVENTORY QUESTIONNAIRE............................................................6 

VII. COMPLIANCE CERTIFICATION.................................................................................................7

VIII. CERTIFICATION OF TRUTH, ACCURACY AND COMPLETENESS......................................7 

IX. INSPECTION AND ENTRY...........................................................................................................8 

X. PERMIT REVISION PURSUANT TO FEDERAL HAZARDOUS AIR 

POLLUTANT STANDARD ..........................................................................................................8

XI. ACCIDENTAL RELEASE PROGRAM .........................................................................................8 

XII. EXCESS EMISSIONS, PERMIT DEVIATIONS, AND EMERGENCY 

REPORTING....................................................................................................................................8 

XIII. RECORD KEEPING REQUIREMENTS......................................................................................14 

XIV. REPORTING REQUIREMENTS..................................................................................................14

XV. DUTY TO PROVIDE INFORMATION .......................................................................................14 

XVI. PERMIT AMENDMENT OR REVISION ....................................................................................15 

XVII. FACILITY CHANGE WITHOUT A PERMIT REVISION .........................................................15 

XVIII. TESTING REQUIREMENTS .......................................................................................................16 

XIX. PROPERTY RIGHTS ....................................................................................................................18 

XX. SEVERABILITY CLAUSE...........................................................................................................18 

XXI. PERMIT SHIELD ..........................................................................................................................18 

XXII. PROTECTION OF STRATOSPHERIC OZONE..........................................................................18 

ATTACHMENT “B” ................................................................................................................................19 

I. FACILITY WIDE SPECIFIC REQUIREMENTS ........................................................................19 

II. UNIT 1 AND UNIT 2 (P1 and P2) ................................................................................................23 

III. UNIT 3 AND UNIT 4 (P3 and P4) ................................................................................................42 

IV. Unit 1, Unit 2, Unit 3 and Unit 4 (P1, P2, P3, and P4)(Combined Limits)....................................75 

V. AUXILIARY BOILER (P5) ..........................................................................................................83 

VI. INTERNAL COMBUSTION ENGINES ......................................................................................85 

VII. COOLING TOWERS.....................................................................................................................93 

VIII. COAL PREPARATION PLANT...................................................................................................97 

IX. LIME HANDLING – UNITS 1 AND 2.......................................................................................100 

X. LIME HANDLING - UNITS 3 AND 4 .......................................................................................102 

XI. FLY ASH HANDLING - UNITS 1 AND 2.................................................................................105 

XII. FLY ASH HANDLING - UNITS 3 AND 4.................................................................................108 

XIII. ACTIVATED CARBON SILO....................................................................................................111 

XIV. EVAPORATIVE WATER SPRAY SYSTEMS (EWS)..............................................................113 

XV. FUGITIVE DUST SOURCES .....................................................................................................114 

XVI. ABRASIVE BLASTING .............................................................................................................116 

XVII. USE OF PAINTS ........................................................................................................................117 
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XVIII. SOLVENT CLEANING / DEGREASING, DIPPING OPERATIONS ......................................118 

XIX. MOBILE SOURCES....................................................................................................................119 

XX. DEMOLITION/RENOVATION..................................................................................................120 

ATTACHMENT “C”: EQUIPMENT LIST ........................................................................................121 

ATTACHMENT “D”: PHASE II ACID RAIN PROVISIONS ..........................................................130
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ATTACHMENT “A”: GENERAL PROVISIONS 

Air Quality Control Permit No. 53418 for 

Tucson Electric Power Company– Springerville Generating Station 

I. PERMIT EXPIRATION AND RENEWAL 

[ARS § 49-426.F, A.A.C. R18-2-304.C.2, and -306.A.1] 

A. This permit is valid for a period of five years from the date of issuance. 

B. The Permittee shall submit an application for renewal of this permit at least 6 

months, but not more than 18 months, prior to the date of permit expiration. 

II. COMPLIANCE WITH PERMIT CONDITIONS [A.A.C. R18-2-306.A.8.a and b] 

A. The Permittee shall comply with all conditions of this permit including all 

applicable requirements of the Arizona air quality statutes and air quality rules. 

Any permit noncompliance constitutes a violation of the Arizona Revised 

Statutes and is grounds for enforcement action; for permit termination, 

revocation and reissuance, or revision; or for denial of a permit renewal 

application. In addition, noncompliance with any federally enforceable 

requirement constitutes a violation of the Clean Air Act. 

B. It shall not be a defense for a Permittee in an enforcement action that it would 

have been necessary to halt or reduce the permitted activity in order to maintain 

compliance with the conditions of this permit. 

III. PERMIT REVISION, REOPENING, REVOCATION AND REISSUANCE, OR 

TERMINATION FOR CAUSE [A.A.C. R18-2-306.A.8.c, -321.A.1, and -.A.2] 

A. The permit may be revised, reopened, revoked and reissued, or terminated for 

cause. The filing of a request by the Permittee for a permit revision, revocation 

and reissuance, termination, or of a notification of planned changes or anticipated 

noncompliance does not stay any permit condition. 

B. The permit shall be reopened and revised under any of the following 

circumstances: 

1. Additional applicable requirements under the Clean Air Act become 

applicable to the Class I source. Such a reopening shall only occur if 

there are three or more years remaining in the permit term. The 

reopening shall be completed no later than 18 months after promulgation 

of the applicable requirement. No such reopening is required if the 

effective date of the requirement is later than the date on which the 

permit is due to expire, unless an application for renewal has been 

submitted pursuant to A.A.C. R18-2-322.B. Any permit revision 

required pursuant to this subparagraph shall comply with the provisions 

in A.A.C. R18-2-322 for permit renewal and shall reset the five-year 

permit term. 
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2. Additional requirements, including excess emissions requirements, 

become applicable to an affected source under the acid rain program. 

Upon approval by the Administrator, excess emissions offset plans shall 

be deemed to be incorporated into the Class I permit. 

3. The Director or the Administrator determines that the permit contains a 

material mistake or that inaccurate statements were made in establishing 

the emissions standards or other terms or conditions of the permit. 

4. The Director or the Administrator determines that the permit needs to be 

revised or revoked to assure compliance with the applicable 

requirements. 

C. Proceedings to reopen and reissue a permit, including appeal of any final action 

relating to a permit reopening, shall follow the same procedures as apply to initial 

permit issuance and shall, except for reopenings under Condition III.B.1 above, 

affect only those parts of the permit for which cause to reopen exists. Such 

reopenings shall be made as expeditiously as practicable. Permit reopenings for 

reasons other than those stated in Condition III.B.1 above shall not result in a 

resetting of the five-year permit term. 

IV. POSTING OF PERMIT [A.A.C. R18-2-315]

A. The Permittee shall post this permit or a certificate of permit issuance where the 

facility is located in such a manner as to be clearly visible and accessible. All 

equipment covered by this permit shall be clearly marked with one of the 

following: 

1. Current permit number; or

2. Serial number or other equipment ID number that is also listed in the 

permit to identify that piece of equipment.

B. A copy of the complete permit shall be kept on site. 

V. FEE PAYMENT [A.A.C. R18-2-306.A.9 and -326] 

The Permittee shall pay fees to the Director pursuant to ARS § 49-426(E) and A.A.C. 

R18-2-326. 

VI. ANNUAL EMISSION INVENTORY QUESTIONNAIRE [A.A.C. R18-2-327.A and B] 

A. The Permittee shall complete and submit to the Director an annual emissions 

inventory questionnaire. The questionnaire is due by March 31st or ninety days 

after the Director makes the inventory form available each year, whichever 

occurs later, and shall include emission information for the previous calendar 

year. 

B. The questionnaire shall be on a form provided by the Director and shall include 

the information required by A.A.C. R18-2-327. 
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VII. COMPLIANCE CERTIFICATION [A.A.C. R18-2-309.2.a, -309.2.c-d, and -309.5.d] 

A. The Permittee shall submit a compliance certification to the Director 

semiannually, which describes the compliance status of the source with respect to 

each permit condition. The first certification shall be submitted no later than 

May 15th, and shall report the compliance status of the source during the period 

between October 1st of the previous year and March 31st of the current year. The 

second certification shall be submitted no later than November 15th, and shall 

report the compliance status of the source during the period between April 1st and 

September 30th of the current year. 

The compliance certifications shall include the following: 

1. Identification of each term or condition of the permit that is the basis of 

the certification; 

2. Identification of the methods or other means used by the Permittee for 

determining the compliance status with each term and condition during 

the certification period, 

3. The status of compliance with the terms and conditions of the permit for 

the period covered by the certification, including whether compliance 

during the period was continuous or intermittent. The certification shall 

be based on the methods and means designated in Condition VII.A.2 

above. The certifications shall identify each deviation and take into 

account for consideration in the compliance certification. 

4. For emission units subject to 40 CFR Part 64, the certification shall also 

identify as possible exceptions to compliance any period during which 

compliance is required and in which an excursion or exceedance defined 

under 40 CFR Part 64 occurred; 

5. All instances of deviations from permit requirements reported pursuant 

to Condition XII.B of this Attachment; and 

6. Other facts the Director may require to determine the compliance status 

of the source. 

B. A copy of all compliance certifications shall also be submitted to the EPA 

Administrator. 

C. If any outstanding compliance schedule exists, a progress report shall be 

submitted with the semi-annual compliance certifications required in Condition 

VII.A above. 

VIII. CERTIFICATION OF TRUTH, ACCURACY AND COMPLETENESS 

[A.A.C. R18-2-304.H] 

Any document required to be submitted by this permit, including reports, shall contain a 

certification by a responsible official of truth, accuracy, and completeness. This 
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certification shall state that, based on information and belief formed after reasonable 

inquiry, the statements and information in the document are true, accurate, and complete. 

IX. INSPECTION AND ENTRY [A.A.C. R18-2-309.4]

Upon presentation of proper credentials, the Permittee shall allow the Director or the 

authorized representative of the Director to: 

A. Enter upon the Permittee’s premises where a source is located, emissions-related 

activity is conducted, or where records are required to be kept under the 

conditions of the permit; 

B. Have access to and copy, at reasonable times, any records that are required to be 

kept under the conditions of the permit; 

C. Inspect, at reasonable times, any facilities, equipment (including monitoring and 

air pollution control equipment), practices, or operations regulated or required 

under the permit; 

D. Sample or monitor, at reasonable times, substances or parameters for the purpose 

of assuring compliance with the permit or other applicable requirements; and 

E. Record any inspection by use of written, electronic, magnetic and photographic 

media. 

X. PERMIT REVISION PURSUANT TO FEDERAL HAZARDOUS AIR 

POLLUTANT STANDARD [A.A.C. R18-2-304.C]

If this source becomes subject to a standard promulgated by the Administrator pursuant 

to Section 112(d) of the Act, then the Permittee shall, within twelve months of the date on 

which the standard is promulgated, submit an application for a permit revision 

demonstrating how the source will comply with the standard. 

XI. ACCIDENTAL RELEASE PROGRAM [40 CFR Part 68] 

If this source becomes subject to the provisions of 40 CFR Part 68, then the Permittee 

shall comply with these provisions according to the time line specified in 40 CFR Part 68. 

XII. EXCESS EMISSIONS, PERMIT DEVIATIONS, AND EMERGENCY 

REPORTING 

A. Excess Emissions Reporting [A.A.C. R18-2-310.01.A and -310.01.B] 

1. Excess emissions shall be reported as follows: 

a. The Permittee shall report to the Director any emissions in 

excess of the limits established by this permit. Such report shall 

be in two parts as specified below: 

(1) Notification by telephone or facsimile within 24 hours of 
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the time when the Permittee first learned of the 

occurrence of excess emissions including all available 

information from Condition XII.A.1.b below. 

(2) Detailed written notification by submission of an excess 

emissions report within 72 hours of the notification 

pursuant to Condition XII.A.1.a.(1) above. 

b. The report shall contain the following information: 

(1) Identity of each stack or other emission point where the 

excess emissions occurred; 

(2) Magnitude of the excess emissions expressed in the units 

of the applicable emission limitation and the operating 

data and calculations used in determining the magnitude 

of the excess emissions; 

(3) Date, time and duration, or expected duration, of the 

excess emissions; 

(4) Identity of the equipment from which the excess 

emissions emanated; 

(5) Nature and cause of such emissions; 

(6) If the excess emissions were the result of a malfunction, 

steps taken to remedy the malfunction and the steps 

taken or planned to prevent the recurrence of such 

malfunctions; and 

(7) Steps taken to limit the excess emissions. If the excess 

emissions resulted from start-up or malfunction, the 

report shall contain a list of the steps taken to comply 

with the permit procedures. 

2. In the case of continuous or recurring excess emissions, the notification 

requirements of this section shall be satisfied if the source provides the 

required notification after excess emissions are first detected and 

includes in such notification an estimate of the time the excess emissions 

will continue. Excess emissions occurring after the estimated time 

period, or changes in the nature of the emissions as originally reported, 

shall require additional notification pursuant to Condition XII.A.1 above. 

[A.A.C. R18-2-310.01.C] 

B. Permit Deviations Reporting [A.A.C. R18-2-306.A.5.b] 

The Permittee shall promptly report deviations from permit requirements, 

including those attributable to upset conditions as defined in the permit, the 

probable cause of such deviations, and any corrective actions or preventive 
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measures taken. Prompt reporting shall mean that the report was submitted to the 

Director by certified mail, facsimile, or hand delivery within two working days of 

the time when emission limitations were exceeded due to an emergency or within 

two working days of the time when the owner or operator first learned of the 

occurrence of a deviation from a permit requirement. 

C. Emergency Provision [A.A.C. R18-2-306.E] 

1. An “emergency” means any situation arising from sudden and 

reasonably unforeseeable events beyond the control of the source, 

including acts of God, that require immediate corrective action to restore 

normal operation, and that causes the source to exceed a technologybased emission limitation under the permit, due to unavoidable increases 

in emissions attributable to the emergency. An emergency shall not 

include noncompliance to the extent caused by improperly designed 

equipment, lack of preventative maintenance, careless or improper 

operation, or operator error. 

2. An emergency constitutes an affirmative defense to an action brought for 

noncompliance with such technology-based emission limitations if 

Condition XII.C.3 is met. 

3. The affirmative defense of emergency shall be demonstrated through 

properly signed, contemporaneous operating logs, or other relevant 

evidence that: 

a. An emergency occurred and that the Permittee can identify the 

cause(s) of the emergency; 

b. The permitted facility was being properly operated at the time; 

c. During the period of the emergency, the Permittee took all 

reasonable steps to minimize levels of emissions that exceeded 

the emissions standards or other requirements in the permit; and 

d. The Permittee submitted notice of the emergency to the Director 

by certified mail, facsimile, or hand delivery within two working 

days of the time when emission limitations were exceeded due to 

the emergency. This notice shall contain a description of the 

emergency, any steps taken to mitigate emissions, and corrective 

action taken. 

4. In any enforcement proceeding, the Permittee seeking to establish the 

occurrence of an emergency has the burden of proof. 

5. This provision is in addition to any emergency or upset provision 

contained in any applicable requirement. 
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D. Compliance Schedule [ARS § 49-426.I.5] 

For any excess emission or permit deviation that cannot be corrected within 72 

hours, the Permittee is required to submit a compliance schedule to the Director 

within 21 days of such occurrence. The compliance schedule shall include a 

schedule of remedial measures, including an enforceable sequence of actions 

with milestones, leading to compliance with the permit terms or conditions that 

have been violated. 

E. Affirmative Defenses for Excess Emissions Due to Malfunctions, Startup, 

and Shutdown [A.A.C. R18-2-310] 

1. Applicability 

This rule establishes affirmative defenses for certain emissions in excess 

of an emission standard or limitation and applies to all emission 

standards or limitations except for standards or limitations: 

a. Promulgated pursuant to Sections 111 or 112 of the Act; 

b. Promulgated pursuant to Titles IV or VI of the Clean Air Act; 

c. Contained in any Prevention of Significant Deterioration (PSD) 

or New Source Review (NSR) permit issued by the U.S. EPA; 

d. Contained in A.A.C. R18-2-715.F; or 

e. Included in a permit to meet the requirements of A.A.C. R18-2-

406.A.5. 

2. Affirmative Defense for Malfunctions 

Emissions in excess of an applicable emission limitation due to 

malfunction shall constitute a violation. When emissions in excess of an 

applicable emission limitation are due to a malfunction, the Permittee has 

an affirmative defense to a civil or administrative enforcement 

proceeding based on that violation, other than a judicial action seeking 

injunctive relief, if the Permittee has complied with the reporting 

requirements of A.A.C. R18-2-310.01 and has demonstrated all of the 

following: 

a. The excess emissions resulted from a sudden and unavoidable 

breakdown of process equipment or air pollution control 

equipment beyond the reasonable control of the Permittee; 

b. The air pollution control equipment, process equipment, or 

processes were at all times maintained and operated in a manner 

consistent with good practice for minimizing emissions; 

c. If repairs were required, the repairs were made in an expeditious 
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fashion when the applicable emission limitations were being 

exceeded. Off-shift labor and overtime were utilized where 

practicable to ensure that the repairs were made as expeditiously 

as possible. If off-shift labor and overtime were not utilized, the 

Permittee satisfactorily demonstrated that the measures were 

impracticable; 

d. The amount and duration of the excess emissions (including any 

bypass operation) were minimized to the maximum extent 

practicable during periods of such emissions; 

e. All reasonable steps were taken to minimize the impact of the 

excess emissions on ambient air quality; 

f. The excess emissions were not part of a recurring pattern 

indicative of inadequate design, operation, or maintenance; 

g. During the period of excess emissions there were no 

exceedances of the relevant ambient air quality standards 

established in Title 18, Chapter 2, Article 2 of the Arizona 

Administrative Code that could be attributed to the emitting 

source; 

h. The excess emissions did not stem from any activity or event 

that could have been foreseen and avoided, or planned, and could 

not have been avoided by better operations and maintenance 

practices; 

i. All emissions monitoring systems were kept in operation if at all 

practicable; and 

j. The Permittee's actions in response to the excess emissions were 

documented by contemporaneous records. 

3. Affirmative Defense for Startup and Shutdown 

a. Except as provided in Condition XII.E.3.b below, and unless 

otherwise provided for in the applicable requirement, emissions 

in excess of an applicable emission limitation due to startup and 

shutdown shall constitute a violation. When emissions in excess 

of an applicable emission limitation are due to startup and 

shutdown, the Permittee has an affirmative defense to a civil or 

administrative enforcement proceeding based on that violation, 

other than a judicial action seeking injunctive relief, if the 

Permittee has complied with the reporting requirements of 

A.A.C. R18-2-310.01 and has demonstrated all of the following: 

(1) The excess emissions could not have been prevented 

through careful and prudent planning and design; 
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(2) If the excess emissions were the result of a bypass of 

control equipment, the bypass was unavoidable to 

prevent loss of life, personal injury, or severe damage to 

air pollution control equipment, production equipment, 

or other property; 

(3) The air pollution control equipment, process equipment, 

or processes were at all times maintained and operated in 

a manner consistent with good practice for minimizing 

emissions; 

(4) The amount and duration of the excess emissions 

(including any bypass operation) were minimized to the 

maximum extent practicable during periods of such 

emissions; 

(5) All reasonable steps were taken to minimize the impact 

of the excess emissions on ambient air quality; 

(6) During the period of excess emissions there were no 

exceedances of the relevant ambient air quality standards 

established in Title 18, Chapter 2, Article 2 of the 

Arizona Administrative Code that could be attributed to 

the emitting source; 

(7) All emissions monitoring systems were kept in operation 

if at all practicable; and 

(8) Contemporaneous records documented the Permittee’s 

actions in response to the excess emissions. 

b. If excess emissions occur due to a malfunction during routine 

startup and shutdown, then those instances shall be treated as 

other malfunctions subject to Condition XII.E.2 above. 

4. Affirmative Defense for Malfunctions during Scheduled Maintenance 

If excess emissions occur due to a malfunction during scheduled 

maintenance, then those instances will be treated as other malfunctions 

subject to Condition XII.E.2 above. 

5. Demonstration of Reasonable and Practicable Measures 

For an affirmative defense under Condition XII.E.2 or XII.E.3 above, the 

Permittee shall demonstrate, through submission of the data and 

information required by Condition XII.E and A.A.C. R18-2-310.01, that 

all reasonable and practicable measures within the Permittee’s control 

were implemented to prevent the occurrence of the excess emissions. 
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XIII. RECORD KEEPING REQUIREMENTS [A.A.C. R18-2-306.A.4] 

A. The Permittee shall keep records of all required monitoring information 

including, but not limited to, the following: 

1. The date, place as defined in the permit, and time of sampling or 

measurements; 

2. The date(s) analyses were performed; 

3. The name of the company or entity that performed the analyses; 

4. A description of the analytical techniques or methods used; 

5. The results of such analyses; and 

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

measurement. 

B. The Permittee shall retain records of all required monitoring data and support 

information for a period of at least 5 years from the date of the monitoring 

sample, measurement, report, or application. Support information includes all 

calibration and maintenance records and all original strip-chart recordings or 

other data recordings for continuous monitoring instrumentation, and copies of 

all reports required by the permit. 

C. All required records shall be maintained either in an unchangeable electronic 

format or in a handwritten logbook utilizing indelible ink. 

XIV. REPORTING REQUIREMENTS [A.A.C. R18-2-306.A.5.a]

The Permittee shall submit the following reports: 

A. Compliance certifications in accordance with Section VII of Attachment “A”. 

B. Excess emission; permit deviation, and emergency reports in accordance with 

Section XII of Attachment “A”. 

C. Other reports required by any condition of Attachment “B”. 

XV. DUTY TO PROVIDE INFORMATION [A.A.C. R18-2-304.G and -306.A.8.e] 

A. The Permittee shall furnish to the Director, within a reasonable time, any 

information that the Director may request in writing to determine whether cause 

exists for revising, revoking and reissuing, or terminating the permit, or to 

determine compliance with the permit. Upon request, the Permittee shall also 

furnish to the Director copies of records required to be kept by the permit. For 

information claimed to be confidential, the Permittee shall furnish an additional 

copy of such records directly to the Administrator along with a claim of 

confidentiality. 
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B. If the Permittee has failed to submit any relevant facts or has submitted incorrect 

information in the permit application, the Permittee shall, upon becoming aware 

of such failure or incorrect submittal, promptly submit such supplementary facts 

or corrected information. 

XVI. PERMIT AMENDMENT OR REVISION [A.A.C. R18-2-318, -319, and -320]

The Permittee shall apply for a permit amendment or revision for changes to the facility 

which do not qualify for a facility change without revision under Section XVII, as 

follows: 

A. Administrative Permit Amendment (A.A.C. R18-2-318); 

B. Minor Permit Revision (A.A.C. R18-2-319); and 

C. Significant Permit Revision (A.A.C. R18-2-320). 

The applicability and requirements for such action are defined in the above referenced 

regulations. 

XVII. FACILITY CHANGE WITHOUT A PERMIT REVISION 

[A.A.C. R18-2-306.A.4 and -317] 

A. The Permittee may make changes at the permitted source without a permit 

revision if all of the following apply: 

1. The changes are not modifications under any provision of Title I of the 

Act or under ARS § 49-401.01(19); 

2. The changes do not exceed the emissions allowable under the permit 

whether expressed therein as a rate of emissions or in terms of total 

emissions; 

3. The changes do not violate any applicable requirements or trigger any 

additional applicable requirements; 

4. The changes satisfy all requirements for a minor permit revision under 

A.A.C. R18-2-319.A; and 

5. The changes do not contravene federally enforceable permit terms and 

conditions that are monitoring (including test methods), record keeping, 

reporting, or compliance certification requirements. 

B. The substitution of an item of process or pollution control equipment for an 

identical or substantially similar item of process or pollution control equipment 

shall qualify as a change that does not require a permit revision, if it meets all of 

the requirements of Conditions XVII.A and XVII.C of this Attachment. 

C. For each change under Conditions XVII.A and XVII.B above, a written notice by 

certified mail or hand delivery shall be received by the Director and the 
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Administrator a minimum of 7 working days in advance of the change. 

Notifications of changes associated with emergency conditions, such as 

malfunctions necessitating the replacement of equipment, may be provided less 

than 7 working days in advance of the change, but must be provided as far in 

advance of the change, as possible or, if advance notification is not practicable, 

as soon after the change as possible. 

D. Each notification shall include: 

1. When the proposed change will occur; 

2. A description of the change; 

3. Any change in emissions of regulated air pollutants; and 

4. Any permit term or condition that is no longer applicable as a result of 

the change. 

E. The permit shield described in A.A.C. R18-2-325 shall not apply to any change 

made under this Section, other than implementation of an alternate to Conditions 

XVII.A and XVII.B above. 

F. Except as otherwise provided for in the permit, making a change from one 

alternative operating scenario to another as provided under A.A.C. R18-2-

306.A.11 shall not require any prior notice under this Section. 

G. Notwithstanding any other part of this Section, the Director may require a permit 

to be revised for any change that, when considered together with any other 

changes submitted by the same source under this Section over the term of the 

permit, do not satisfy Condition XVII.A above. 

XVIII. TESTING REQUIREMENTS [A.A.C. R18-2-312] 

A. The Permittee shall conduct performance tests as specified in the permit and at 

such other times as may be required by the Director. 

B. Operational Conditions during Testing 

Tests shall be conducted during operation at the full load of each unit under 

representative operational conditions unless other conditions are required by the 

applicable test method or in this permit. With prior written approval from the 

Director, testing may be performed at a lower rate. Operations during periods of 

start-up, shutdown, and malfunction (as defined in A.A.C. R18-2-101) shall not 

constitute representative operational conditions unless otherwise specified in the 

applicable standard. 

C. Tests shall be conducted and data reduced in accordance with the test methods 

and procedures contained in the Arizona Testing Manual unless modified by the 

Director pursuant to A.A.C. R18-2-312.B. 
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D. Test Plan 

At least 14 calendar days prior to performing a test, the Permittee shall submit a 

test plan to the Director in accordance with A.A.C. R18-2-312.B and the Arizona 

Testing Manual. This test plan must include the following: 

1. Test duration; 

2. Test location(s); 

3. Test method(s); and 

4. Source operation and other parameters that may affect test results. 

E. Stack Sampling Facilities 

The Permittee shall provide, or cause to be provided, performance testing 

facilities as follows: 

1. Sampling ports adequate for test methods applicable to the facility; 

2. Safe sampling platform(s); 

3. Safe access to sampling platform(s); and 

4. Utilities for sampling and testing equipment. 

F. Interpretation of Final Results 

Each performance test shall consist of three separate runs using the applicable 

test method. Each run shall be conducted for the time and under the conditions 

specified in the applicable standard. For the purpose of determining compliance 

with an applicable standard, the arithmetic mean of the results of the three runs 

shall apply. In the event that a sample is accidentally lost or conditions occur in 

which one of the three runs is required to be discontinued because of forced 

shutdown, failure of an irreplaceable portion of the sample train, extreme 

meteorological conditions, or other circumstances beyond the Permittee’s 

control, compliance may, upon the Director’s approval, be determined using the 

arithmetic mean of the results of the other two runs. If the Director or the 

Director’s designee is present, tests may only be stopped with the Director’s or 

such designee’s approval. If the Director or the Director’s designee is not 

present, tests may only be stopped for good cause. Good cause includes: forced 

shutdown, failure of an irreplaceable portion of the sample train, extreme 

meteorological conditions, or other circumstances beyond the Permittee’s 

control. Termination of any test without good cause after the first run is 

commenced shall constitute a failure of the test. Supporting documentation, 

which demonstrates good cause, must be submitted. 
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G. Report of Final Test Results 

A written report of the results of all performance tests shall be submitted to the 

Director within 30 days after the test is performed. The report shall be submitted 

in accordance with the Arizona Testing Manual and A.A.C. R18-2-312.A. 

XIX. PROPERTY RIGHTS [A.A.C. R18-2-306.A.8.d] 

This permit does not convey any property rights of any sort, or any exclusive privilege. 

XX. SEVERABILITY CLAUSE [A.A.C. R18-2-306.A.7]

The provisions of this permit are severable. In the event of a challenge to any portion of 

this permit, or if any portion of this permit is held invalid, the remaining permit 

conditions remain valid and in force. 

XXI. PERMIT SHIELD [A.A.C. R18-2-325] 

Compliance with the conditions of this permit shall be deemed compliance with all 

applicable requirements identified in the portions of this permit subtitled “Permit Shield”. 

The permit shield shall not apply to minor revisions pursuant to Condition XVI.B of this 

Attachment and any facility changes without a permit revision pursuant to Section XVII 

of this Attachment. 

XXII. PROTECTION OF STRATOSPHERIC OZONE [40 CFR Part 82] 

If this source becomes subject to the provisions of 40 CFR Part 82, then the Permittee 

shall comply with these provisions accordingly. 
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ATTACHMENT “B”: SPECIFIC REQUIREMENTS 

Air Quality Control Permit No. 53418 for 

Tucson Electric Power Company– Springerville Generating Station 

I. FACILITY WIDE GENERAL REQUIREMENTS 

A. The Permittee shall have on site or on call a person that is certified in EPA 

Reference Method 9. [A.A.C R18-2-306.A.3.c] 

B. At the time the compliance certifications required by Section VII of Attachment 

“A” are submitted, the Permittee shall submit reports of all monitoring activities 

required by Attachment “B” performed during the six month compliance term. 

[A.A.C. R18-2-306.A.5.a] 

C. The permit conditions or portions of the permit conditions which are material 

pursuant to A.A.C. R18-2-331 and A.R.S. §49-464 are indicated by italics and a 

single underline. 

D. Definitions 

The terms used in this permit shall have the following meaning: 

1. “Boiler operating day” [40 CFR 60.41Da]

a. For units constructed, reconstructed, or modified on or before 

February 28, 2005, means a 24-hour period during which fossil 

fuel is combusted in a steam generating unit for the entire 24 

hours. 

b. For units constructed, reconstructed, or modified after February 

28, 2005, means a 24-hour period between 12 midnight and the 

following midnight during which any fuel is combusted at any 

time in the steam-generating unit. It is not necessary for fuel to 

be combusted the entire 24-hour period. 

2. “Calendar Day” means any 24-hour period between 12:00 midnight and 

the following midnight in Arizona. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D Ariz.), §3(b)] 

3. “Cooling Tower 1” and “Cooling Tower 2” are the existing mechanicaldraft wet cooling towers at the Springerville Generating Station (SGS). 

 [Condition No. I.B.2. of Attachment “B” of Significant Permit Revision No. 1001554 to Permit No. 1000105] 

4. “Cooling Tower 3” and “Cooling Tower 4” are the new mechanical-draft 

wet cooling towers at the SGS associated with Unit 3 & Unit 4. 

[Condition No.I.B.3. of Attachment “B” of Significant Permit Revision No. 1001554 to Permit No. 1000105] 

5. “Gross Output” means the gross useful work performed by the steam 

generated. The gross useful work performed is equal to the gross 

electrical output from the turbine/generator set. [40 CFR 60.41Da] 
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6. “Heat Input” means the aggregate gross calorific value of all fuels whose 

products of combustion pass through a stack or other outlet. The gross 

calorific value of solid and liquid fuels shall be determined in accordance 

with appropriate test methods that are incorporated by reference at 40 

CFR 60.17 or A.A.C. R18-2-724. 

[A.A.C. R18-2-724 and 40 CFR Part 60, Appendix A, Method 19] 

7. “Major Burner Malfunction” is, for the purposes of complying with the 

NOx emission limitation in Condition II.E.1.c, a malfunction (as defined 

in Condition I.D.8) that is unanticipated and that requires extensive 

repairs to the low NOx burners and the Secondary Overfire Air dampers 

that are internal to the boiler at Unit 1 or 2. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(f)] 

8. Malfunction means any sudden, infrequent, and not reasonably 

preventable failure of air pollution control equipment, process 

equipment, or a process to operate in a normal or usual manner. Failures 

that are caused in part by poor maintenance or careless operation are not 

malfunctions. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(e)] 

9. “NOx” means total oxides of nitrogen, except nitrous oxide, which are 

expressed as nitrogen dioxide (NO2) using EPA Reference Method 7. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(g)] 

10. “Potential combustion concentration” means the theoretical emissions 

that would result from combustion of a fuel without emission control 

systems. [40 CFR 60.41Da and A.A.C. R18-2-406.A.4] 

11. “PM” or “Particulate Matter” mean any airborne, finely divided solid or 

liquid material, other than uncombined water, with an aerodynamic 

diameter smaller than 100 micrometers, and which is expressed as PM 

using EPA Reference. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(j)] 

12. “Shutdown” means the cessation of operation of a steam generating unit 

for any purpose. [40 CFR 60.2] 

13. “SO2” means sulfur dioxide. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(l)] 

14. “Startup” means the setting in operation of a steam generating unit for 

any purpose. [40 CFR 60.2] 

15. “Steam generating unit” shall mean Unit 1, Unit 2, Unit 3, or Unit 4. For 

the purposes of Unit 1 and Unit 2, this term shall have the same meaning 

as “fossil-fuel fired steam generating unit” as defined at 40 CFR 

60.41(a). For the purposes of Unit 3 and Unit 4, this term shall have the 

same meaning as “electric utility steam generating unit” as defined in 40 

CFR 60.41Da. 

[Condition No.I.B.12 of Attachment “B” of Significant Permit Revision No. 1001554 to Permit No. 1000105] 
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16. Unit means Unit 1, Unit 2, Unit 3, or Unit 4. 

17. “Unit 1” and “Unit 2” 

Unit 1 and Unit 2 are the existing steam generating units at the SGS. 

 [Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 3(o)] 

[Condition No.I.B.13 of Attachment “B” of Significant Permit Revision No. 1001554 to Permit No. 1000105] 

18. “Unit 3” and “Unit 4” 

Unit 3 and Unit 4 are steam generating units at the SGS. Each of these 

units is an “affected facility” under 40 CFR Part 60, Subpart Da, 

“Standards of Performance for Electric Utility Steam Generating Units 

for which Construction Commenced after September 18, 1978.” 

[Condition No.I.B.14 of Attachment “B” of Significant Permit Revision No. 1001554 to Permit No. 1000105] 

19. For purposes of the sulfur dioxide standard in Condition II.D.1.d and the 

nitrogen oxide standard in Condition II.E.1.c, the following terms shall 

be defined as follows: 

a. “Emission Rate” means the total amount of a pollutant emitted 

from an emission unit during a given time period, expressed in 

lbs/MMBtu, derived for SO2 and NOx from a SO2 or NOx

continuous emission monitoring system and diluent (O2 or CO2) 

monitoring system consistent with 40 CFR Part 75. 

b. “Hourly Average” means the calculated arithmetic average 

hourly emission rate, expressed in lbs/MMBtu, derived from an 

SO2 and/or NOx continuous emission monitoring system and 

diluent (CO2 or O2) monitoring system consistent with 40 CFR 

75, collected during an hour, beginning on the hour. 

c. “Daily Average” means the arithmetic average of the Hourly 

Averages for a Unit in a Day. 

d. “Combined Daily Average” means the arithmetic average of the 

Daily Averages of Unit 1 and Unit 2 on a given day. For days 

when only one Unit has any operating hours, the Combined 

Daily Average shall be the Daily Average for that Unit. 

e. “Monthly Average” means the arithmetic average of the 

Combined Daily Average Emission Rates for Units 1 and 2 for a 

calendar month. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 17(d)] 

20. For purposes of the sulfur dioxide control efficiency in Condition 

II.D.1.e, the following terms shall be defined as follows: 

a. “Hourly Average Stack Outlet Sulfur Dioxide Concentration” 

means the calculated arithmetic average hourly emission rate, 
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expressed in lbs/MMBtu, derived from an SO2 and/or NOx

continuous emission monitoring system and diluent (CO2 or O2) 

monitoring system consistent with 40 CFR 75, collected during 

an hour, beginning on the hour, using the SGS existing SO2

Continuous Emission Monitoring System. 

b. “Hourly Average Boiler Inlet Sulfur Dioxide Concentrations” 

means the calculated hourly inlet sulfur dioxide concentration, 

expressed in lbs/MMBtu, derived from all valid measurements or 

data points collected from the monitoring system (referred to in 

Condition II.B.1.d.(3)) during an hour, beginning on the hour; 

provided however, that: 

(1) in the event the monitoring system is not in operation 

due to maintenance and/or malfunction, the Permittee 

shall substitute for each hour the average sulfur dioxide 

concentration from the previous 30 days of data from 

such monitoring system; and 

(2) if the monitoring system has not yet been in service for 

30 days, the Permittee shall use the previous 30 days of 

coal analysis as received from the coal vendor. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 18(f)] 

E. For the purposes of this permit, unless otherwise specified in the applicable 

standards, for any facilities subject to the new source performance standards 

(NSPS) from 40 CFR Part 60, compliance with such standards other than opacity 

standards shall be determined in accordance with performance tests. The 

performance tests shall be conducted and data reduced in accordance with the test 

methods and procedures contained in the specific requirements for each emission 

unit or group of emission units. [40 CFR 60.8(b) and 60.11(a)] 

F. For the purposes of this permit, for any facilities subject to the NSPS from 40 

CFR Part 60, compliance with the new source opacity standards shall be 

determined by conducting observations in accordance with EPA Reference 

Method 9, or any alternative method that is approved by the Director, unless the 

Permittee elects to submit continuous opacity monitoring system data for 

compliance with the opacity standards. [40 CFR 60.11(b)] 

G. For the purposes of submitting compliance certifications or establishing whether 

or not Permittee has violated or is in violation of any NSPS from 40 CFR Part 60 

subsumed under Attachment “B”, nothing in Attachment “B” shall preclude the 

use, including the exclusive use, of any credible evidence or information, 

relevant to whether a source would have been in compliance with such standards 

if the appropriate performance or compliance test or procedure had been 

performed. [40 CFR 60.11(g)] 

H. For the purposes of this permit, the EPA Reference Method 9 reading shall be 

defined as an average of 24 consecutive opacity observations recorded at 15-

second intervals. A set is composed of any 24 consecutive observations. Sets 
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need not be consecutive in time and in no case shall two sets overlap. For each 

set of 24 observations, calculate the average by summing the opacity of the 24 

observations and dividing this sum by 24. 

[A.A.C. R18-2-306.A.3.b and 40 CFR Part 60, Appendix A, Method 9] 

II. UNIT 1 AND UNIT 2 (P1 and P2) 

A. Applicability

This Section applies to Unit 1 and Unit 2 as described in Condition I.D.17 and 

Equipment List, Attachment “C”. 

B. Operating Limitations 

1. Fuel Limitations 

a. Unit 1 [A.A.C. R18-2-306.A.2 and A.R.S. 49.426.G.1]

(1) The Permittee shall burn only the following as fuel in 

Unit 1: 

(a) Coal; 

(b) Co-firing of coal and fuel oil including biodiesel; 

(c) Co-firing of coal and used oil subject to the 

limits specified in Conditions II.B.1.a.(2) and 

(3); and 

(d) Fuel oil during times of startup and shut down. 

(2) The maximum amount of used oil consumed in Unit 1 

shall not exceed 2,500 gallons per hour, based on a 

calendar-day block average, or 100,000 gallons per year, 

based on a 12-month rolling total. 

(3) The Permittee shall only burn on-specification used oil 

or on-site generated on-specification used oil fuel (onspec used oil) along with coal in the Unit 1, if the 

following conditions are met: 

(a) The flash point of the on-spec used oil does not 

fall below 100o

 Fahrenheit. 

(b) The Permittee shall comply with all applicable 

requirements of A.R.S. §49-801 through §49-

803- Management of Used Oil. 
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(c) The on-spec used oil shall not contain 

contaminants in excess of the levels indicated in 

Table 1: 

 Table 1: Contaminant Levels

b. Unit 2 [A.A.C. R18-2-306.A.2] 

The Permittee shall burn only the following as fuel in Unit 2: 

(1) Coal; 

(2) Co-firing of coal and fuel oil including bio-diesel; and 

(3) Fuel oil during times of startup and shut down. 

c. Monitoring/Recordkeeping/Reporting Requirements 

(1) The Permittee shall keep a record of any change in fuel 

type at Unit 1 and Unit 2 including: 

 (a) Type of the fuel change; 

 (b) Date of the fuel change; and 

 (c) Time of the fuel change. 

[A.A.C. R18-2-306.A.3.c] 

(2) Used Oil [A.R.S § 49-426.G.4] 

(a) All analyses of used oil performed pursuant to 

Condition II.B.1.d(1) shall be documented and a 

report submitted to the Department along with 

the compliance certification. 

(b) The Permittee shall maintain such records as 

required to document the use of used oil 

including the following: 

(i) Dates on which used oil was burned; 

Name of 

Pollutant

Limit

Arsenic 5 ppm 

Cadmium 2 ppm 

Chromium 10 ppm 

Lead 100 ppm 

Halogens 1000 ppm 

PCBs 2 ppm 
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(ii) Hours used oil was burned; and 

(iii) The quantity of used oil burned. 

d. Testing Requirements 

(1) Used Oil 

The Permittee shall perform or cause to be performed an 

analysis of a representative sample of any used oil to be 

combusted in Unit 1. The analysis shall include flash 

point and concentrations (ppm) of Arsenic, Cadmium, 

Chromium, and Lead using the analytical methods 

specified in EPA Publication SW-846, Third Edition, 

including update III B (document number 955-001-

00000-1). All sample analyses shall be conducted in 

laboratories certified by the Arizona Department of 

Health Services. [A.R.S.§ 49-426.G.2]

(2) Coal Sampling 

Coal shall be sampled before entering the boilers. The 

sample shall be analyzed for moisture, ash, sulfur 

content, and gross calorific value. Analysis of coal 

samples provided by the coal supplier may be utilized 

for this purpose. The results of these analyses shall be 

retained for at least five years following the date of 

measurements. All sampling, sample preparation, and 

analyses performed or caused to be performed shall be 

performed as per the current ASTM standard methods. 

[Condition XI of EPA Approval to Construct of December 2, 1977] 

(3) Monitoring Systems 

The Permittee shall operate either an in-line elemental 

coal analyzer upstream of both the Unit 1 and Unit 2 

boilers, which will be available to both Units, or an “asfired” fuel monitoring system (upstream of the coal 

pulverizer) meeting the requirements of EPA Reference 

Method 19 in 40 CFR 60 to determine the potential 

sulfur dioxide inlet concentration. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 7] 

2. Vapor Extractor Blower Vents, Generator Seal Oil Vapor Extractor and 

Hydraulic Fluid Reservoir Vapor Extractors [A.A.C. R18-2-730.F]

The Permittee shall process, store, use, and transport materials including 

solvents or volatile compounds in such a manner and by such means that 

they will not evaporate, leak, escape, or be otherwise discharged into the 

atmosphere so as to cause or contribute to air pollution. Where means 
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are available to reduce effectively the contribution to air pollution from 

evaporation, leakage, or discharge, the installation and usage of such 

control methods, devices, or equipment shall be mandatory. 

3. Good Air Pollution Control Practices. 

The Permittee shall at all times, including periods of startup, shutdown, 

and malfunction (as defined in Condition #s I.D.8, 12, and 14), maintain 

and operate Unit 1 and Unit 2 in a manner consistent with good air 

pollution control practices for minimizing emissions. Without limiting 

the Permittee’s obligations in the event of a malfunction, from and after 

the effective date of this Permit, the Permittee shall address each 

malfunction affecting Unit 1 or Unit 2 and take corrective action, when 

possible, within 24 hours of when the Permittee first learns of the 

malfunction. Malfunctions that cannot be corrected within a 24 hour 

period shall be reported to the ADEQ within two (2) business days and a 

plan for bringing the affected Unit(s) into compliance shall be submitted 

to the ADEQ within seven (7) business days, unless the malfunction can 

be corrected within seven (7) business days. 

 [Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 15]

4. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R18-2-730.F, Condition XI of EPA Approval to 

Construct of December 2,1977 and Consent Decree of June 24, 2005, 

CV01-2189 PCT EHC (D. Ariz.), § 15. 

 

C. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity 

The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 1 or Unit 2 any gases which 

exhibit greater than 15 percent opacity except for periods of 

startup, shutdown, and malfunction as defined in Condition #s

I.D.8, 12, and 14. [40 CFR 60.11(c) and A.A.C. R18-2-331.A.3.f] 

[Condition XIII of Approval to Construct of December 21, 1977] 

[Material Permit Conditions are defined by underline and italics] 

b. Particulate Matter 

(1) The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 1 and Unit 2 any 

gases which contain PM/PM10 in excess of 0.034 lb per 

million Btu derived from fossil fuel except for periods of 

startup, shutdown, and malfunction as defined in 

Condition #s I.D.8, 12, and 14. 

[Condition XIII of Approval to Construct of December 21, 1977 and 40 CFR 60.8 (c)] 
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(2) Unless otherwise specified, the PM/PM10 emission limit 

defined above shall be measured by manual testing on a 

one-hour average (the average of three one-hour tests). 

[A.A.C. R18-2-312] 

(3) The Permittee shall not cause to be discharged to the 

atmosphere from the stacks of Unit 1 and Unit 2 any 

gases which contain PM/PM10 in excess of 0.03 

lb/MMBtu derived from fossil fuel, except for periods of 

startup, shutdown, or malfunction as defined in 

Condition #s I.D.8, 12, and 14.

 [Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 11] 

2. Air Pollution Control Requirements 

[40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e] 

[Material Permit Conditions are defined by underline and italics] 

At all times when the equipment is in operation, including periods of 

startup, shutdown, and malfunction as defined in Condition #s I.D.8, 12, 

and 14, the Permittee shall, to the extent practicable, maintain and

operate four (4) Joy baghouses in a manner consistent with good air 

pollution control practice for minimizing PM/PM10 emissions.

3. Monitoring, Recordkeeping, and Reporting Requirements 

a. Opacity 

(1) Monitoring for Opacity 

(a) The Permittee shall calibrate, maintain, and 

operate continuous monitoring systems, and 

shall record the output of the systems, for 

measuring the opacity of emissions discharged 

to the atmosphere from Unit 1 and Unit 2.

[40 CFR 60.45(a), A.A.C. R18-2-306.A.3, and -331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

(b) The Permittee shall comply with all 

recordkeeping and reporting requirements of 40 

CFR Part 75, Subparts F and G respectively. 

(c) The continuous opacity monitoring systems 

(COMS) shall meet the following data reduction 

requirements: [40 CFR 60.13(h)] 

(i) The Permittee shall reduce all data from 

the COMS to 6-minute averages. Sixminute opacity averages shall be 

calculated from 36 or more data points 

equally spaced over each 6-minute 

period. 
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(ii) Data recorded during periods of system 

breakdowns, repairs, calibration checks, 

and zero and span adjustments shall not 

be included in the data averages 

computed under the previous paragraph. 

An arithmetic or integrated average of 

all data may be used. 

(2) NSPS Requirements for Continuous Monitoring Systems 

The continuous opacity monitoring system for opacity as 

required by Condition II.C.3.a.(1)(a) shall meet the 

following requirements: 

(a) Calibration requirements at 40 CFR 60.13(d) 

(b) Operational requirements at 40 CFR 60.13(e) 

(c) Performance Specifications at 40 CFR Part 60, 

Appendix B. 

(d) Notification and recordkeeping requirements at 

40 CFR 60.7. 

b. Compliance Assurance Monitoring for Particulate Matter 

(1) The Permittee shall maintain and continuously operate 

Continuous Opacity Monitoring Systems (COMS) to 

measure visible emissions (Opacity) which is indicative 

of operation of the Unit 1 and Unit 2 fabric filters in a 

manner necessary to comply with PM/PM10 emission 

standards. The fabric filter parameters are identified in 

Table 2. [40 CFR 64.6(c)(1) and A.A.C. R18-2-306.A.3.c] 

Table 2: Summary of CAM Requirements applicable to Unit 1 and Unit 2 (PM Limits)

Indicators Indicator No. 1: Visible Emissions 

Opacity

Indicator No. 2: Bag condition. 

Measurement Approach Visible Emissions (Opacity) will be 

measured continuously with a 

continuous Opacity Monitoring 

System (COMS) installed on each 

stack. 

Sampling and analysis of representative bag samples 

will be done once per year. The analyses of 

representative bag samples will be used as a factor in 

determining when bag replacement is to be scheduled. 

The Baghouse will have an inspection and 

maintenance program that includes an internal 

inspection of the baghouse to be performed during a 

scheduled major outage. Any known broken bags 

will be either replaced or capped off until ready to be 

replaced. Compartments with one or more broken 

bags, that have not been capped off or replaced, will 

be isolated. 
Permit #53418 29 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Indicators Indicator No. 1: Visible Emissions 

Opacity

Indicator No. 2: Bag condition. 

Visible Emissions greater than 12 

percent Opacity based on a 3-hour 

rolling average (except during unit 

startup, shutdown, and malfunction 

as defined in Condition #s. I.D.8, 12, 

and 14 above). 

An excursion is defined as failure to sample and 

analyze bag condition at least once per year. 

Excursions trigger an inspection, corrective action, 

and a reporting requirement. 

Indicator Range

An excursion from the indicator ranges does not necessarily indicate an exceedance, 

deviation, or violation, but is indicative of the need for investigation and possible corrective 

action to minimize the potential for an exceedance, deviation, or violation. 

Performance Criteria - 

Data 

Representativeness

Visible emissions (Opacity is 

measured on stack) 

Scheduled internal baghouse inspection includes a 

visual inspection of the entire baghouse including 

individual bag compartments for signs of bag failure. 

Performance Criteria - 

Operation Status

n/a n/a 

Performance Criteria - 

QA/QC Practices

TEP is required by the permit to 

meet the QA/QC requirements of 40 

CFR Part 60, Appendix B, 

Performance Specification 1, 

“Specification and Test Procedures 

for Opacity Continuous Emission 

Monitoring Systems in Stationary 

Sources” 

Experienced personnel perform inspections and 

maintenance. 

Performance Criteria - 

Monitoring Frequency

Continuous opacity monitoring with 

data recorded as 6-minute averages. 

Varies. 

Performance Criteria - 

Data Collection 

Procedure 

Continuous Results of inspections and maintenance activities 

performed are recorded. Results of annual bag 

analysis are kept on-file. 

Performance Criteria - 

Averaging Period 

3-hour rolling average of visible 

emissions (Opacity) 

n/a 

(2) A three-hour rolling average opacity, except during 

startup, shutdown, and malfunction (as defined in 

Condition #s I.D.8, 12, and 14 above) of 12 percent or 

greater shall constitute an excursion.

[40 CFR 64.3(a)(2) and A.A.C. R18-2-306.A.3.b] 

(3) The three-hour rolling average opacity parameter shall 

be equipped with an alarm. 

[40 CFR 64.6(c)(1) and A.A.C. R18-2-306.A.3.b] 

(4) Each three-hour rolling average opacity of 12 percent or 

greater, except during startup, shutdown and malfunction 

(defined in Condition #s I.D.8, 12, and 14 above), during 

which a fabric filter parameter alarm is activated shall 

constitute an excursion for the purposes of responding to 

and reporting excursions under 40 CFR 64.7. 

[40 CFR 64.6(c)(2) and A.A.C. R18-2-306.A.3.b] 
Permit #53418 30 of 131 August 15, 2012 

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(5) Prior to making any changes to the alarm set point or 

alarm delay time, the Permittee shall submit written 

notification to the Department. Such notification shall 

include the proposed new alarm set point or alarm delay 

time and the reason for the proposed change. The 

proposed change may be made without the prior 

approval of the Department. 

[40 CFR 64.6(c)(2) and A.A.C. R18-2-306.A.3.b] 

(6) The Permittee shall conduct monitoring in accordance 

with the following provisions: 

[40 CFR 64.7(c) and A.A.C. R18-2-306.A.3.b] 

(a) Conduct all monitoring in continuous operation 

(or shall collect data at all required intervals) at 

all times that the pollutant specific emission unit 

(PSEU) is operating. Except for, as applicable, 

monitoring malfunctions, associated repairs, and 

required quality assurance or control activities 

(including, as applicable, calibration checks and 

required zero and span adjustments). 

(b) Data recorded during monitoring malfunctions, 

associated repairs, and required quality 

assurance or control activities shall not be used 

for purposes of this part, including data averages 

and calculations, or fulfilling a minimum data 

availability requirement, if applicable. 

(7) The Permittee shall, to the extent practicable, respond to 

excursions as follows: 

[40 CFR 64.7(d) and A.A.C. R18-2-306.A.3.b] 

(a) The Permittee upon detecting an excursion or 

exceedance, shall restore operation of the PSEU 

(including the control device and associated 

capture system) to its normal or usual manner of 

operation as expeditiously as practicable in 

accordance with good air pollution control 

practices for minimizing emissions. 

(b) The Permittee shall, to the extent practicable, 

minimize the period of any startup, shutdown, or 

malfunction (as defined in Condition #s I.D.8, 

12, and 14 above) and take any necessary 

corrective actions to restore normal operation 

and prevent the likely recurrence of the cause of 

an excursion or exceedance (other than those 

caused by excused startup, shutdown, 

malfunction). 
Permit #53418 31 of 131 August 15, 2012 

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(8) For the purposes of permit deviation reporting under 

Condition XII of Attachment “A”, the Permittee shall 

include the following information required by 40 CFR 

Part 64, § 64.9(a): [40 CFR 64.7(d) and A.A.C. R18-2-306.A.3.b] 

(a) Summary information on the number, duration 

and cause (including unknown cause, if 

applicable) of excursions or exceedances, as 

applicable, and the corrective action taken: 

(b) Summary information on the number, duration 

and cause (including unknown cause, if 

applicable) for monitoring downtime incidents 

(other than downtime associated with zero and 

span or other daily calibration checks). 

c. Excess Emissions 

(1) Excess emission and monitoring system performance 

(MSP) reports for Unit 1 and Unit 2 shall be submitted 

to the Department and EPA Region IX for every 

calendar quarter. All quarterly reports shall be 

postmarked by the 30th day following the end of each 

calendar quarter. Each excess emission and MSP report 

shall include the information required in Condition 

II.C.3.c.(2) below. Periods of excess emissions and 

monitoring systems (MS) downtime that shall be 

reported are defined as follows: [40 CFR 60.45(g)] 

Opacity 

Excess emissions for Unit 1 and Unit 2 are defined as 

any six-minute period during which the average opacity 

of emissions exceeds 15 percent opacity except for 

periods of startup, shutdown, or malfunction as defined 

in Condition #s I.D.8, 12, and 14. [40 CFR 60.45(g)(1)] 

[Condition No. II.C.4.a (1) of Attachment “B” of Significant Revision No. 1001554 to Title V Permit No. 1000105] 

(2) The summary quarterly report form submission required 

in Condition II.C.3.c (1) shall be in the format specified 

in 40 CFR 60.7(d). The excess emissions report shall 

include the following information: [40 CFR 60.7(c)]

(a) The magnitude of excess emissions computed, 

any conversion factor(s) used, the date and time 

of commencement and completion of each time 

period of excess emissions, and the process 

operating time during the reporting period. 

(b) Specific identification of each period of excess 

emissions that occurs during startups, 

shutdowns, and malfunctions (as defined in 

Condition #s I.D.8, 12, and 14) of the affected 
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facility, the nature and cause of any malfunction 

(if known), and the corrective action taken or 

preventative measures adopted. 

(c) The date and time identifying each period during 

which the COMS was inoperative except for 

zero and span checks and the nature of the 

system repairs or adjustments. 

(d) When no excess emissions have occurred, or the 

COMS(s) have not been inoperative, repaired, or 

adjusted, such information shall be stated in the 

report. 

(3) In addition to reports under Conditions II.C.3.c (1) and 

(2), the Permittee shall report emissions exceeding an 

emission limitation or standard in accordance with 

Section XII.B of Attachment “A” of this permit. 

4. Testing Requirements 

a. Emission Rate Calculation 

(1) The emission rate (E) of particulate matter shall be 

calculated for each test run using the following equation: 

[40 CFR 60.46 (b)(1)] 

E = C Fd (20.9)/ (20.9 - % O2) 

E = emission rate of pollutant, ng/J (1b/million Btu). 

C = concentration of pollutant, ng/dscm (1b/dscf). 

%O2 = oxygen concentration, percent dry basis. 

Fd = factor as determined from Method 19. 

(2) As an alternative to Condition II.C.4.a (1), the Permittee 

may follow the methodology specified in 40 CFR § 

60.46(d)(1) to determine the emission rate (E) of 

particulate matter. [40 CFR 60.46 (d)(1)] 

b. Particulate Matter [A.A.C.R18-2-306.A.3.c and - 312] 

The Permittee shall perform an annual performance test to 

determine the particulate matter concentration using EPA 

Reference Method 5. 

5. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with Condition XIII of Approval to Construct of December 

21, 1977, 40 CFR 60.45 (a), (g). (g)(1), 60.46 (b)(1), and (d)(1). 
Permit #53418 33 of 131 August 15, 2012 

Tucson Electric Power-SGS 

D. Sulfur Dioxide (SO2)

1. Emission Limitations/Standard. 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 1 and Unit 2 any gases which 

contain SO2 in excess of 0.690 pounds per million Btu derived 

from fossil fuel except for periods of startup, shutdown, and 

malfunction as defined in Condition #s I.D.8, 12, and 14. 

[Condition XIII of Approval to Construct of December 21, 1977 and 40 CFR §60.8(c)] 

b. Compliance shall be based on the total heat input from all fossil 

fuels burned. [40 CFR 60.43 (c)] 

c. Unless otherwise specified, the SO2 emission limit defined in 

Condition II.D.1.a shall be measured by manual testing on a onehour average (the average of three one-hour tests). [A.A.C. R18-2-312] 

d. At all times, including periods of startup, shutdown, and/or 

malfunction (as defined in Condition #s I.D.8, 12, and 14), the 

Permittee shall not cause to be discharged to the atmosphere 

from the stack of Unit 1 and Unit 2 any gases which contain SO2 

in excess of 0.27 pounds per million Btu derived from fossil 

fuels, based on a 12-month rolling average, averaged over Unit 1 

and Unit 2. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 8] 

e. At all times, except for periods of startup, shutdown, and/or 

malfunction (as defined in Condition #s I.D.8, 12, and 14), SO2

emissions from Unit 1 and Unit 2 shall be limited to 15 percent 

or less of the potential boiler inlet SO2 concentration (85 percent 

reduction) based on a 90-day rolling average, averaged over 

Units 1 and Unit 2. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 9]

2. Air Pollution Control Requirements 

At all times when the system is in operation, including periods of startup, 

shutdown, and malfunction as defined in Condition #s I.D.8, 12, and 14, 

the Permittee shall, to the extent practicable, maintain and operate the 

Niro dry flue gas desulfurization systems in a manner consistent with 

good air pollution control practice for minimizing SO2 emissions.

[40 CFR 60.11 (d) and A.A.C. R18-2-331.A.3.e] 

[Material Permit Conditions are defined by underline and italics] 

3. Monitoring, Recordkeeping, and Reporting Requirements 

a. The Permittee shall calibrate, maintain, and operate continuous 

monitoring systems for measuring SO2 emissions.

[40 CFR 60.45 (a) and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 
Permit #53418 34 of 131 August 15, 2012 

Tucson Electric Power-SGS 

b. The continuous emission monitoring systems (CEMS) for SO2

shall meet the following requirements: 

(1) 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

(a) Installation and measurement location 

(b) Equipment specifications 

(c) Performance specifications 

(d) Data acquisition and handling systems 

(e) Calibration gas 

(f) Certifications tests and procedures 

(g) Calculations 

(2) 40 CFR Part 75, Appendix B, “Quality Assurance and 

Quality Control Procedure” 

(a) Quality control program 

(b) Frequency of testing 

(3) Data Reduction 

The Permittee shall comply with the data reduction 

requirements of 40 CFR Part 75.10 (d)(1). 

c. The Permittee shall comply with all applicable recordkeeping 

and reporting requirements of 40 CFR Part 75 Subparts F and G 

respectively. 

d. Excess Emissions 

(1) Excess emission and monitoring system performance 

(MSP) reports for Unit 1 and Unit 2 shall be submitted 

to the Department and EPA Region IX for every 

calendar quarter. All quarterly reports shall be 

postmarked by the 30th day following the end of each 

calendar quarter. Each excess emission and MSP report 

shall include the information required in Condition 

II.D.3.d (2). Periods of excess emissions and monitoring 

systems (MS) downtime that shall be reported are 

defined as follows: [40 CFR 60.45 (g)] 
Permit #53418 35 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Sulfur Dioxide

Excess emissions for Unit 1 and Unit 2 are defined as 

any three-hour period during which the average 

emissions (arithmetic average of three contiguous onehour periods) of SO2 as measured by a continuous 

monitoring system are in excess of the applicable 

standard in Condition II.D.1.a. [40 CFR 60.45 (g)(2)] 

(2) The summary quarterly report form submission required 

in Condition II.D.3.d (1) shall be in the format specified 

in 40 CFR 60.7(d). The excess emissions report shall 

include the following information: [40 CFR 60.7 (c)] 

(a) The magnitude of excess emissions computed, 

any conversion factor(s) used, the date and time 

of commencement, completion of each time 

period of excess emissions, and the process 

operating time during the reporting period. 

(b) Specific identification of each period of excess 

emissions that occurs during startups, 

shutdowns, malfunctions (as defined in 

Condition #s I.D.8, 12, and 14) of the affected 

facility, the nature and cause of any malfunction 

(if known), the corrective action taken or 

preventative measures adopted. 

(c) The date and time identifying each period during 

which the CEMS was inoperative except for 

zero and span checks and the nature of the 

system repairs or adjustments. 

(d) When no excess emissions have occurred or the 

CEMS have not been inoperative, repaired, or 

adjusted, such information shall be stated in the 

report. 

(3) In addition to the reports under Conditions II.D.3.d (1) 

and (2), the Permittee shall report emissions exceeding 

an emission limitation or standard in accordance with 

Condition XII.B, Attachment “A”. [A.A.C. R18-2-306.A.5.b]

e. Monitoring for the Permittee’s compliance with the SO2

emission limit in Condition II.D.1.d shall be determined as 

follows: 

(1) The Permittee shall record Hourly Average Emission 

Rate (as defined in Condition #s I.D.19.a and b) data for 

SO2 in lbs/MMBtu for each hour of Unit operation. 
Permit #53418 36 of 131 August 15, 2012 

Tucson Electric Power-SGS 

(2) Each calendar month, the Permittee shall calculate a 12-

month rolling average emission rate calculated as the 

arithmetic average of the immediately prior 12 Monthly 

Averages (as defined in Condition I.D.19.e), in 

lbs/MMBtu. This calculation shall be made available for 

review by the fifth working day following the end of 

each rolling 12-month average period. 

(3) If the calculated 12-month rolling average emission rate 

exceeds the applicable mass emission limit set forth in 

Condition II.D.1.d, the Permittee shall be in violation of 

such mass emission limit, and shall be deemed to have 

been in violation for each day in the last occurring 

calendar month included in the calculation of such 12-

month rolling average emission rate. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 17] 

(4) Unless explicitly specified elsewhere in this Permit, all 

average emission rates shall: 

(a) Include all periods of startup, shutdown, and 

malfunction (as defined in Condition #s I.D.8, 

12, and 14) and emergency; and 

(b) Exclude the following: 

(i) data for a Unit on a day that has not 

operated for at least one hour; 

(ii) data for a Unit from periods when the 

Unit is not operating; and 

(iii) Other inappropriate data as specified in 

the applicable EPA testing regulations at 

40 CFR Part 60, Appendix A, and Part 

75 (e.g., from periods of malfunction by 

the monitoring system). 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 19] 

f. Monitoring for SO2 Control Efficiency 

The Permittee’s compliance with the SO2 reduction requirement 

in Condition II.D.2.b shall be determined as follows: 

(1) The Permittee shall separately record, except for periods 

of startup, shutdown or malfunction (as defined in 

Conditions #s I.D.8, 12, or 14), 

(a) Hourly Average Boiler Inlet SO2Concentrations 

(as defined in Condition I.D.20.b), and 
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Tucson Electric Power-SGS 

(b) Hourly Average Stack Outlet SO2Concentrations 

(as defined in Condition I.D.20.a), for Unit 1 

and Unit 2. 

(2) For each Calendar Day, the Permittee shall calculate: 

(a) the arithmetic average of the Hourly Average 

Boiler Inlet SO2Concentrations, expressed in 

lbs/MMBtu, for each of Unit 1 and Unit 2 in a 

day (the “Combined Daily Inlet Average”), and 

(b) the arithmetic average of the Hourly Average 

Stack Outlet SO2Concentrations, expressed in 

lbs/MMBtu, for each of Unit 1 and Unit 2 in that 

day (the “Combined Daily Outlet Average”). 

(3) For each Calendar Day, the Permittee shall calculate the 

daily average SO2 reduction rate for Unit 1 and 2 as 

follows: (Combined Daily Inlet Average – Combined 

Daily Outlet Average)/ Combined Daily Inlet Average, 

expressed as a percentage (the “Daily Average 

Reduction Rate”). 

(4) For each Calendar Day, the Permittee shall calculate and 

record a 90-day rolling average Daily Average 

Reduction Rate calculated as the arithmetic average of 

the immediately prior 90 Daily Average Reduction 

Rates. 

(5) If that average calculated above is less than the 85 

percent SO2 reduction requirement in Condition II.D.2.b, 

the Permittee shall be in violation of such SO2 reduction 

requirement for the last occurring Calendar Day included 

in the calculation of such 90-day rolling average 

Reduction Rate. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 18] 

(6) Unless explicitly specified elsewhere in this Permit, all 

average emission reduction efficiencies shall include all 

period of emergency and exclude the following: 

(a) data for Unit on a day that has not operated for 

at least one hour; 

(b) data for a Unit from periods when the Unit is not 

operating; and 

(c) other inappropriate data as specified in the 

applicable EPA testing regulations at 40 CFR 

Part 60, Appendix A, and Part 75 (e.g., from 
Permit #53418 38 of 131 August 15, 2012 

Tucson Electric Power-SGS 

periods of malfunction by the monitoring 

system). 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 19] 

4. Testing Requirements [A.A.C.R18-2-306.A.3.c & 312] 

The Permittee shall perform an annual performance test to determine the 

sulfur dioxide concentration using EPA Reference Method 6 or 6C. 

5. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with Condition XIII of Approval to Construct of December 

21, 1977, Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. 

Ariz.), § 17 & 19, 40 CFR 60.43 (c), 60.45 (a), (g), and (g)(2).

E. Nitrogen Oxides (NOx)

1. Emission Limitations/Standards 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 1 and Unit 2 any gases which 

contain nitrogen oxides, expressed as NO2 in excess of 0.697 

pounds per million Btu derived from fossil fuel except for 

periods of startup, shutdown, and malfunction as defined in 

Condition #s I.D.8, 12, and 14. 

[Condition XIII of Approval to Construct of December 21, 1977 and 40 CFR §60.8(c)] 

b. Unless otherwise specified, the NOx emission limit in Condition 

II.E.1.a shall be measured by manual testing on a one-hour 

average (the average of three one-hour tests). [A.A.C. R18-2-312] 

c. At all times, except for periods of major burner malfunction (as 

defined in Condition I.D.7 of this Attachment), the Permittee 

shall not cause to be discharged to the atmosphere from the 

Stack of Unit 1 and Unit 2 any gases which contain nitrogen 

oxides, expressed as NO2, in excess of 0.22 lb/MMBtu derived 

from fossil fuel, based on a 12-month rolling average over Unit 1 

and Unit 2. The exception for periods of operation during a 

major burner malfunction is applicable only if: 

(1) The Permittee reports the major burner malfunction to 

ADEQ within two (2) business days and, 

(2) Within seven (7) business days, the Permittee provides 

ADEQ with a compliance plan to correct the major 

burner malfunction as expeditiously as practicable. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 10] 
Permit #53418 39 of 131 August 15, 2012 

Tucson Electric Power-SGS 

2. Monitoring/Recordkeeping/Reporting Requirements 

a. The Permittee shall calibrate, maintain, and operate continuous 

monitoring systems for measuring the NOx emissions and CO2. [40 CFR 60.45 (a) and A.A.C. R18-2-331.a.3.c] 

[Material Permit Conditions are defined by underline and italics] 

b. The continuous emission monitoring systems for NOx and CO2 

shall meet the following requirements: 

(1) 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

(a) Installation and measurement location 

(b) Equipment specifications 

(c) Performance specifications 

(d) Data acquisition and handling systems 

(e) Calibration gas 

(f) Certifications tests and procedures 

(g) Calculations 

(2) 40 CFR Part 75, Appendix B, “Quality Assurance and 

Quality Control Procedure” 

(a) Quality control program 

(b) Frequency of testing 

(3) Data Reduction 

The Permittee shall comply with the data reduction 

requirements of 40 CFR Part 75.10 (d)(1). 

c. The Permittee shall comply with all applicable recordkeeping 

and reporting requirements of 40 CFR Part 75 Subparts F and G 

respectively. 

d. Excess Emissions 

(1) Excess emission and monitoring system performance 

(MSP) reports for Unit 1 and Unit 2 shall be submitted 

to the Department and EPA Region IX for every 

calendar quarter. All quarterly reports shall be 

postmarked by the 30th day following the end of each 

calendar quarter. Each excess emission and MSP report 
Permit #53418 40 of 131 August 15, 2012 

Tucson Electric Power-SGS 

shall include the information required in Condition 

II.E.2.d (2). Periods of excess emissions and monitoring 

systems (MS) downtime that shall be reported are 

defined as follows: [40 CFR 60.45 (g)] 

Nitrogen Oxides 

Excess emissions for Unit 1 and Unit 2 are defined as 

any three-hour period during which the average 

emissions (arithmetic average of three contiguous onehour periods) of nitrogen oxides as measured by a 

continuous monitoring system are in excess of the 

applicable standard in Condition II.E.1.a.. 

[40 CFR 60.45 (g)(2)] 

(2) The summary quarterly report form submission required 

in paragraph II.E.2.d (1) shall be in the format specified 

in 40 CFR 60.7(d). The excess emissions report shall 

include the following information: [40 CFR 60.7 (c)] 

(a) The magnitude of excess emissions computed, 

any conversion factor(s) used, the date and 

time of commencement and completion of 

each time period of excess emissions, and the 

process operating time during the reporting 

period. 

(b) 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), and the corrective 

action taken or preventative measures adopted. 

(c) The date and time identifying each period 

during which the CMS was inoperative except 

for zero and span checks and the nature of the 

system repairs or adjustments. 

(d) When no excess emissions have occurred or 

the CMS(s) have not been inoperative, 

repaired, or adjusted, such information shall 

be stated in the report. 

(3) In addition to reports under Conditions II.E.2.d (1) and-

(2), the Permittee shall report emissions exceeding an 

emission limitation or standard in accordance with 

Section XII.B of Attachment “A” of this permit. 

[A.A.C. R18-2-306.A.5.b] 
Permit #53418 41 of 131 August 15, 2012 

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e. Monitoring for NO2 emission limit in Condition II.E.1.c 

The Permittee’s compliance with the NO2 emission limit in 

Condition II.E.1.c shall be determined as follows: 

(1) The Permittee shall record Hourly Average Emission 

Rate (as defined in Condition I.D.19.a and b) data for 

NOx in lbs/MMBtu for each hour of Unit operation. 

(2) The Permittee shall, for each calendar month, calculate a 

12-month rolling average emission rate calculated as the 

arithmetic average of the immediately prior 12 Monthly 

Averages (as defined in Condition I.D.19.e), in 

lbs/MMBtu. This calculation shall be made available for 

review by the fifth working day following the end of 

each rolling 12-month average period. 

(3) If the calculated 12-month rolling average emission rate 

exceeds the applicable mass emission limit set forth in 

Specific Condition II.E.1.c, the Permittee shall be in 

violation of such mass emission limit, and shall be 

deemed to have been in violation for each Day in the last 

occurring calendar month included in the calculation of 

such 12-month rolling average emission rate. 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 17] 

(4) Unless explicitly specified elsewhere in this Permit, all 

average emission rates shall include all periods of 

startup, shutdown, and malfunction (as defined in 

Condition #s. I.D.8, 12, and 14), and emergency and 

exclude the following: 

(a) data for Unit on a day that has not operated for 

at least one hour; 

(b) data for a Unit from periods when the Unit is not 

operating; and 

(c) other inappropriate data as specified in the 

applicable EPA testing regulations at 40 CFR 

Part 60, Appendix A, and Part 75 (e.g., from 

periods of malfunction by the monitoring 

system). 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 19] 

3. Testing Requirements

The Permittee shall perform an annual performance test to determine the 

nitrogen oxides concentration using EPA Reference Method 7 or 7E. 

[A.A.C.R18-2-306.A.3.c & -312] 

[Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. Ariz.), § 14] 
Permit #53418 42 of 131 August 15, 2012 

Tucson Electric Power-SGS 

4. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with Condition XIII Approval to Construct of December 21, 

1977, Consent Decree of June 24, 2005, CV01-2189 PCT EHC (D. 

Ariz.), § 10, 14, 17, & 19, 40 CFR 60.45 (a), (g), and (g)(2). 

III. UNIT 3 AND UNIT 4 (P3 and P4) 

A. Applicability 

This Section applies to Unit 3 and Unit 4 as described in Condition I.D.18 and 

Equipment List, Attachment “C”. 

B. Operating Limitations 

1. Fuel Limitations 

a. The Permittee shall burn only coal and No. 2 distillate oil 

including bio-diesel as fuel in Unit 3 and Unit 4. 

[A.A.C. R18-2-306.A.2] 

b. The Permittee shall not allow or permit the heat input from all 

fuels to exceed 4,200 million Btu per hour for Unit 3 or Unit 4. 

Compliance with this heat input limitation shall be based on a 

30-day rolling average. [A.A.C. R18-2-406.A.4] 

c. The Permittee shall maintain the following records: 

[A.A.C. R18-2-306.A.4] 

(1) Date, time, types of fuels, and ranks of coal burned in 

each boiler unit; and 

(2) 30-day rolling average of heat input in million Btu per 

hour from all fuels to each unit. 

2. Vapor Extractor Blower Vents, Generator Seal Oil Vapor Extractor, and 

Hydraulic Fluid Reservoir Vapor Extractors [A.A.C. R18-2-730.F] 

The Permittee shall process, store, use, and transport materials including 

solvents or volatile compounds in such a manner and by such means that 

they will not evaporate, leak, escape, or be otherwise discharged into the 

atmosphere so as to cause or contribute to air pollution. Where means 

are available to reduce effectively the contribution to air pollution from 

evaporation, leakage, or discharge, the installation and usage of such 

control methods, devices, or equipment shall be mandatory. 

3. Unit 4 Fuel Oil Storage Tank 

a. The Permittee shall not emit gaseous or odorous material from 

equipment, operations, or premises under his control in such 
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quantities or concentrations as to cause air pollution. 

[A.A.C. R18-2-730.D] 

b. The Permittee shall process, store, use, and transport materials 

including solvents or volatile compounds in such a manner and 

by such means that they will not evaporate, leak, escape, or be 

otherwise discharged into the atmosphere so as to cause or 

contribute to air pollution. Where means are available to reduce 

effectively the contribution to air pollution from evaporation, 

leakage, or discharge, the installation and usage of such control 

methods, devices, or equipment shall be mandatory. 

[A.A.C. R18-2-730.F] 

c. Where a stack, vent or other outlet is at such a level that fumes, 

gas mist, odor, smoke, vapor or any combination thereof 

constituting air pollution is discharged to adjoining property, the 

Director may require the installation of abatement equipment or 

the alteration of such stack, vent, or other outlet by the Permittee 

thereof to a degree that will adequately dilute, reduce or 

eliminate the discharge of air pollution to adjoining property. 

[A.A.C. R18-2-730.G] 

4. Mercury General Provisions 

a. The Permittee shall comply with the following applicable 

requirements: 

(1) The Permittee shall develop and implement a written 

startup, shutdown, and malfunction plan as defined in 

Condition #s. I.D.8, 12, and 14. The plan shall describe 

in detail, procedures for operating and maintaining Unit 

3 and Unit 4 during periods of startup, shutdown, and 

malfunction and a program of corrective action for 

malfunctioning process and air pollution control 

equipment used to comply with the relevant emission 

standards. 

[Condition No. III.E.1. of Significant Permit Revision No. 1001554 to Title V Permit No. 1000105] 

(2) For the purposes of Condition III.B.4.a (1), each of the 

fabric filter baghouses and dry flue gas desulfurization 

systems required by Conditions III.C.2.a and III.D.2, 

shall be considered air pollution control equipment. 

[Condition No. III.E.2. of Significant Permit Revision No. 1001554 to Title V Permit No. 1000105] 

5. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C. R 18-2-730.D, F, and G.
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C. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity Standard 

The Permittee shall not cause to be discharged into the 

atmosphere from the stack of Unit 3 or Unit 4 any gases which 

exhibit greater than 15 percent opacity, based on a six-minute 

average, except for periods of startup, shutdowns, or 

malfunction as defined in Condition #s I.D.8, 12, and 14.

[40 CFR 60.42 Da(b), A.A.C. R18-2-331.A.3.f, and -406.A.4] 

[Material Permit Conditions are defined by underline and italics] 

b. Particulate Matter Emission Standards 

(1) The Permittee shall not cause to be discharged into the 

atmosphere from the stack of Unit 3 or Unit 4 any gases 

which contain particulate matter in excess of 0.015 lb 

per million Btu heat input derived from combustion of 

fuel (excluding condensable particulate matter). 

Compliance with this emission limit shall be determined 

using a three-hour averaging period. [A.A.C. R18-2-406.A.4] 

(2) The Permittee shall not cause to be discharged into the 

atmosphere from the stack of Unit 3 or Unit 4 any gases 

which contain PM10 (including both filterable PM10 and 

condensable PM10) in excess of 0.055 lb per million Btu 

heat input derived from combustion of fuel. Compliance 

with this emission limit shall be determined using a 

three-hour averaging period. [A.A.C. R18-2-406.A.4] 

(3) The particulate matter emission limits in Conditions 

III.C.1.b(1) and (2) shall apply at all times except during 

periods of startup, shutdown, or malfunction as defined 

in Condition #s I.D.8, 12, and 14. [A.A.C. R18-2-406.A.4] 

(4) NSPS Subpart Da limit for Unit 4 

[40 CFR 60.42Da (c), (d), and 60.48Da (g)(3)] 

(a) The Permittee shall not cause to be discharged 

into the atmosphere from the stack of Unit 4 any 

gases which contain particulate matter in excess 

of either 0.14 lb/MWh gross energy output; or 

0.015 lb/MMBtu heat input derived from the 

combustion of solid, or liquid fuel. 

(b) As an alternative to meeting the above 

requirements for Unit 4, the Permittee may elect 

to not exceed 0.03 lb/MMBtu heat input derived 

from the combustion of solid or liquid fuel and 
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99.9 percent reduction. Compliance with the 

daily average particulate matter emission 

limitations is determined by calculating the 

arithmetic average of all hourly emission rates 

for particulate matter each boiler operating day, 

except for data obtained during startup, 

shutdown, and malfunction. 

2. Air Pollution Control Requirements 

a. At all times when the equipment is in operation, including 

periods of startup, shutdown, and malfunction as defined in 

Condition #s I.D.8, 12, and 14, the Permittee shall, to the extent 

practicable, maintain and operate the fabric filter baghouses in a 

manner consistent with good air pollution control practice for 

minimizing particulate matter emissions.

[40 CFR 60.11 (d) and A.A.C. R18-2-331.A.3.e] 

[Material Permit Conditions are defined by underline and italics] 

b. The fabric filter baghouses shall not be bypassed, except during 

periods of startup or shutdown (as defined in Condition #s I.D.12 

and 14) while Unit 3 or Unit 4 is combusting fossil fuel. [A.A.C. R18-2-406.A.4] 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Opacity 

(1) Monitoring for Opacity 

(a) The Permittee shall calibrate, maintain, and 

operate continuous monitoring systems, and 

shall record the output of the systems, for 

measuring the opacity of emissions discharged 

to the atmosphere from Unit 3 and Unit 4.

[40 CFR 60.49Da (a), 75.10 (a), A.A.C. R18-2-331.A.3.c, and -406.A.4] 

[Material Permit Conditions are defined by underline and italics] 

(b) The continuous opacity monitoring systems 

(COMS) shall meet the following data reduction 

requirements: [40 CFR 60.13 (h)]

(i) The Permittee shall reduce all data from 

the COMS to 6-minute averages. Sixminute opacity averages shall be 

calculated from 36 or more data points 

equally spaced over each 6-minute 

period. 

(ii) Data recorded during periods of system 

breakdowns, repairs, calibration checks, 
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and zero and span adjustments shall not 

be included in the data averages 

computed under the previous paragraph. 

An arithmetic or integrated average of 

all data may be used. 

(2) NSPS Requirements for Continuous Monitoring Systems 

for Unit 3 & Unit 4 

The COMS required by Condition III.C.3.a(1)(a), shall 

meet the following: 

(a) Calibration requirements at 40 CFR 60.13(d). 

(b) Operational requirements at 40 CFR 60.13(e). 

(c) Performance Specifications at 40 CFR Part 60, 

Appendix B. 

(d) Notification and recordkeeping requirements at 

40 CFR 60.7. 

(3) Acid Rain Program Requirements for Continuous 

Monitoring Systems 

The COMS required by Condition III.C.3.a(1)(a), shall 

meet all applicable requirements at 40 CFR Part 75. 

This shall include, but shall not be limited to, the 

following: 

(a) Hourly operating requirements at 40 CFR 

75.10(d) 

(b) Data reduction requirements at 40 CFR 

75.10(d)(2) 

(c) Certification and recertification requirements at 

40 CFR 75.20. 

(4) The Permittee shall comply with all applicable 

recordkeeping and reporting requirements of 40 CFR 

Part 75, Subparts F and G, respectively. 

b. Compliance Assurance Monitoring for Particulate Matter 

(1) The Permittee shall maintain and continuously operate 

the COMS to measure visible emissions (Opacity) which 

is indicative of operation of the Unit 3 and Unit 4 fabric 

filter in a manner necessary to comply with particulate 

matter emission standards. The fabric filter parameters 
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have been identified in Table 4. 

[40 CFR 64.6 (c)(1), A.A.C. R18-2-306.A.3.c., and -406.A.4] 

Table 4: Units 3 and Unit 4 PM CAM for Fabric Filter Baghouses

Indicators Indicator No. 1: Visible Emissions Opacity 

Measurement Approach Visible Emissions (Opacity) will be measured continuously with a continuous Opacity 

Monitoring System (COMS) installed on each stack. 

Indicator Range Visible Emissions on a 24-hour rolling average basis not to exceed an opacity baseline level 

established during each performance test conducted according to Condition III.C.4.b. The 

value of the opacity baseline level is determined by averaging all of the 6-minute average 

opacity values (reported to the nearest 0.1 percent opacity) from the COMS measurements 

recorded during each of the test run intervals conducted for the performance test, and then 

adding 5.0 percent opacity to the calculated average opacity value for all of the test runs. The 

value of the baseline level shall not exceed 8.0 percent. 

A 24-hour rolling average opacity excluding periods of facility startup, shutdown and 

malfunction that is greater than the established opacity baseline level triggers an alarm and 

constitutes an excursion. Each subsequent 24-hour rolling period during which the alarm 

continues for the same reason shall be considered a single excursion. 

An excursion from the indicator ranges does not necessarily indicate an exceedance, deviation, 

or violation, but is indicative of the need for investigation and possible corrective action to 

minimize the potential for an exceedance, deviation or violation. 

Performance Criteria - 

Data 

Representativeness

Visible emissions (Opacity is measured on stack) 

Performance Criteria - 

Operation Status

n/a 

Performance Criteria - 

QA/QC Practices

TEP is required by the permit to meet the QA/QC requirements of 40 CFR Part 60, Appendix 

B, Performance Specification 1, “Specification and Test Procedures for Opacity Continuous 

Emission Monitoring Systems in Stationary Sources” 

Performance Criteria - 

Monitoring Frequency

Continuous opacity monitoring with data recorded as 6-minute averages. 

Performance Criteria - 

Data Collection 

Procedure 

Continuous 

Performance Criteria - 

Averaging Period 

Initiate investigation and possible corrective action within 24 hours of triggering an excursion 

for Unit 3 or Unit 4. 

 (2) A twenty four-hour rolling average opacity, except 

during startup, shutdown, and malfunction (as defined in 

Condition #s I.D.8, 12, and 14) that is greater than the 

established baseline opacity shall constitute an 

excursion. 

[40 CFR 64.3 (a)(2), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(3) The twenty four-hour rolling average opacity parameter 

shall be equipped with an alarm.

[40 CFR 64.6 (c)(1), A.A.C. R18-2-306.A.3.b, and -406.A.4] 
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(4) A twenty-four-hour average opacity excluding periods of 

facility startup, shutdown and malfunction (as defined in 

Condition #s I.D.8, 12, and 14) that is greater than the 

established opacity baseline level triggers an alarm and 

constitutes an excursion. Each subsequent 24-hour 

rolling period during which the alarm continues for the 

same reason shall be considered a single excursion under 

40 CFR Part 64, § 64.7. 

[40 CFR 64.6 (c)(2), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(5) Prior to making any changes to the alarm set point, the 

Permittee shall submit written notification to the 

Department. Such notification shall include the 

proposed new alarm set point and the reason for the 

proposed change. The proposed change may be made 

without the prior approval of the Department. 

[40 CFR 64.6 (c)(2), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(6) The Permittee shall conduct monitoring in accordance 

with the following provisions. 

[40 CFR 64.7 (c), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(a) The Permittee shall conduct all monitoring in 

continuous operation (or shall collect data at all 

required intervals) at all times that the pollution 

specific emission unit (PSEU) is operating. 

Except for, as applicable, monitoring 

malfunctions, associated repairs, and required 

quality assurance or control activities (including, 

as applicable, calibration checks and required 

zero and span adjustments). 

(b) Data recorded during monitoring malfunctions, 

associated repairs, and required quality 

assurance or control activities shall not be used 

for purposes of this part, including data averages 

and calculations, or fulfilling a minimum data 

availability requirement, if applicable. 

 (7) The Permittee shall to the extent practicable respond to 

excursions as follows. 

[40 CFR 64.7 (d), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(a) The Permittee upon detecting an excursion or 

exceedance shall restore operation of the PSEU 

(including the control device and associated 

capture system) to its normal or usual manner of 

operation as expeditiously as practicable in 

accordance with good air pollution control 

practices for minimizing emissions. 
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(b) The Permittee shall, to the extent practicable, 

minimize the period of any startup, shutdown, or 

malfunction and take any necessary corrective 

actions to restore normal operation and prevent 

the likely recurrence of the cause of an 

excursion or exceedance (other than those 

caused by excused startup, shutdown, and 

malfunction conditions (as defined in Condition 

#s I.D.8, 12, and 14)). 

(8) For the purposes of permit deviation reporting under 

Condition XII of Attachment “A”, the Permittee shall 

include the following information required by 40 CFR 

Part 64, § 64.9(a): 

[40 CFR 64.7 (d), A.A.C. R18-2-306.A.3.b, and -406.A.4] 

(a) Summary information on the number, duration 

and cause (including unknown cause, if 

applicable) of excursions or exceedances, as 

applicable, and the corrective action taken: 

(b) Summary information on the number, duration 

and cause (including unknown cause, if 

applicable) for monitoring downtime incidents 

(other than downtime associated with zero and 

span or other daily calibration checks). 

c. NSPS Subpart Da Monitoring Requirements for Unit 4 

(1) If the output-based emissions limitation for Unit 4 under 

Condition III.C.1.b(4) is used to demonstrate compliance 

then the Permittee shall certify, operate, and maintain a

continuous monitoring system for measuring particulate 

matter emissions. If the input-based emission limitation 

for Unit 4 under Condition III.C.1.b(4) is used to 

demonstrate compliance then the Permittee as an option 

may install, certify, operate, and maintain a continuous 

monitoring system for measuring particulate matter in 

lieu of Condition III.C.3.c(2).

[40 CFR 60.49 Da (t) and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

(2) The Permittee shall monitor the performance of fabric 

filter baghouse associated with Unit 4 by utilizing the 

COMS required by Condition III.C.3.a.(1)(a). In 

addition to the requirements of Conditions III.C.3.a.(1) 

and (2), the Permittee shall operate the COMS according 

to the following requirements: 

[40 CFR 60.48 Da (o)(2),(2)(i), and (ii)] 
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(a) During each Unit 4 performance test conducted 

in accordance with Condition III.C.4.b.(1), the 

Permittee shall establish an opacity baseline 

level. The value of the opacity baseline level is 

determined by averaging all of the 6-minute 

average opacity values (reported to the nearest 

0.1 percent opacity) from the COMS 

measurements recorded during each of the test 

run intervals conducted for the performance test, 

and then adding 2.5 percent opacity to the 

calculated average opacity value for all of the 

test runs. If the calculated average value plus 

2.5 percent is less than 5.0 percent, then the 

opacity baseline level is set at 5.0 percent. 

[40 CFR 60.48 Da (o)(2)(iii)] 

(b) The Permittee shall evaluate the preceding 24-

hour average opacity level measured by the 

COMS each boiler operating day excluding 

periods of affected facility startup, shutdown, or 

malfunction. If the measured 24-hour average 

opacity emission level is greater than the 

baseline opacity level determined in Condition 

III.C.3.c.(2)(a), the Permittee shall initiate 

investigation of the relevant equipment and 

control systems within 24 hours of the first 

discovery of the high opacity incident and take 

the appropriate corrective action as soon as 

practicable to adjust control settings or repair 

equipment to reduce the measured 24-hour 

average opacity to a level below the baseline 

opacity level. [40 CFR 60.48 Da (o)(2)(iv)] 

(c) The Permittee shall record the opacity 

measurements, calculations performed, and any 

corrective actions taken. The record of 

corrective action taken shall include the date and 

time during which the measured 24-hour 

average opacity was greater than baseline 

opacity level, and the date, time, and description 

of the corrective action. [40 CFR 60.48 Da (o)(2)(v)] 

d. NSPS Subpart Da Reporting Requirements 

(1) For PM emissions, the performance test data from the 

performance test and from the performance evaluation of 

the continuous monitors (including the transmissometer) 

shall be submitted to the Director and the Administrator. [40 CFR 60.51 Da (a)] 
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(2) For any periods for which opacity emissions data are not 

available, the Permittee shall submit a signed statement 

indicating if any changes were made in operation of the 

emission control system during the period of data 

unavailability. Operations of the control system and 

Unit 3 and Unit 4 during periods of data unavailability 

are to be compared with operations of the control system 

and affected facility before and following the period of 

data unavailability. [40 CFR 60.51 Da (f)] 

(3) The Permittee shall submit a signed statement indicating 

whether: [40 CFR 60.51 Da (h)] 

(a) The required continuous monitoring system 

calibration, span, and drift checks or other 

periodic audits have or have not been performed 

as specified. 

(b) The data used to show compliance was or was 

not obtained in accordance with approved 

methods and procedures of 40 CFR 60 and is 

representative of plant performance. 

(c) The minimum data requirements have or have 

not been met; or, the minimum data 

requirements have not been met for errors that 

were unavoidable. 

(d) Compliance with the standards has or has not 

been achieved during the reporting period. 

(4) For the purposes of the reports required under 40 CFR 

60.7 and this permit, periods of excess emissions are 

defined as all 6-minute periods during which the average 

opacity exceeds the applicable opacity standards under 

40 CFR 60.42Da(b) and III.C.1.a of this permit. Opacity 

levels in excess of the applicable opacity standard and 

the date of such excesses are to be submitted to the 

Department and the Administrator each calendar quarter. [40 CFR 60.51 Da (i)] 

(5) The Permittee shall submit the written reports required 

under this section and 40 CFR 60 Subpart A to the 

Director and the Administrator semiannually for each 

six-month period. All semiannual reports shall be 

postmarked by the 30th day following the end of each 

six-month period. [40 CFR 60.51 Da (j)] 

(6) The Permittee may submit electronic quarterly reports 

for opacity in lieu of submitting the written reports 
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required under Condition III.C.3.d (4). The format of 

each quarterly electronic report shall be coordinated with 

the Director. The electronic report(s) shall be submitted 

no later than 30 days after the end of the calendar quarter 

and shall be accompanied by a certification statement 

from the Permittee, indicating whether compliance with 

the applicable emission standards and minimum data 

requirements of 40 CFR 60 Subpart Da was achieved 

during the reporting period. Before submitting reports in 

the electronic format, the Permittee shall coordinate the 

Director to obtain their agreement to submit reports in 

this alternative format. [40 CFR 60.51Da (k)] 

(7) The Permittee shall prepare and submit to the Director 

and the Administrator for approval a unit-specific 

monitoring plan for each monitoring system, at least 45 

days before commencing certification testing of the 

monitoring systems. The Permittee shall comply with the 

requirements in the plan. The plan must address the 

requirements of 40 CFR 60.49Da(s)(1) through (6). 

 [40 CFR 60.49 Da (s)] 

4. Testing 

a. Opacity 

(1) The Permittee shall perform annual performance tests to 

determine compliance with the opacity limitations in 

Condition III.C.1.a. [40 CFR 60.8 and A.A.C.R18-2-306.A.3.c] 

(2) All performance tests for opacity shall be performed in 

accordance with 40 CFR 60.8 and 60.11. [40 CFR 60.8]

b. Particulate Matter 

(1) The Permittee shall perform annual performance tests to 

determine compliance with the PM/PM10 emission 

limitations in Condition #s III.C.1.b(1), b(2), and b(4). 

[40 CFR 60.8 and A.A.C.R18-306.A.3.c] 

(2) If the measured 24-hour average opacity for Unit 4 

remains at a level greater than the opacity baseline level 

after 7 boiler operating days, then the Permittee shall 

conduct a PM performance test and establish a new 

opacity baseline value according to Condition 

III.C.3.c(2)(a). This new performance test shall be 

conducted within 60 days of the date that the measured 

24-hour average opacity was first determined to exceed 

the baseline opacity level unless a waiver is granted by 

the Director. [40 CFR 60.48 Da (o)(2)(vi)] 
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(3) All performance tests for particulate matter shall be 

performed in accordance with 40 CFR 60.8. EPA 

Reference Method 5 shall be used. [40 CFR 60.8] 

(4) All performance tests for PM10 shall be performed in 

accordance with the provisions of 40 CFR 60.8. EPA 

Reference Method 5 or 201 or 201A shall be used for 

filterable PM10 and EPA Reference Method 202 shall be 

used for condensable PM10. Testing for filterable and 

condensable PM10 shall be performed concurrently. 

Testing for PM10 may be performed concurrently with 

testing for particulate matter. [40 CFR 60.8] 

(5) The dry basis F factor (O2) procedures in EPA Reference 

Method 19 shall be used to calculate the PM and PM10

emission rates. 

[40 CFR 60.50 Da (b)(1) and A.A.C. R18-2-406A.4] 

(6) As an alternative to the dry basis F factor (O2) 

procedures in EPA Reference Method 19, the Fc CO2

factors in EPA Reference Method 19 may be used to 

calculate the particulate matter and PM10 emission rates, 

subject to the stipulations of 40 CFR Part 60, Subpart D, 

60.46(d)(1). [40 CFR 60.50 Da (e)(2)] 

(7) The sampling time and sample volume for each test run 

shall be at least 120 minutes and 60 dry standard cubic 

feet. [40 CFR 60.50 Da (b)(2)(i)] 

5. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with 40 CFR 60.42Da(b), (c), & (d), 60.48Da(g)(3), (o)(2), 

(o)(2)(i), (o)(2)(ii), (o)(2)(iii), (o)(2)(iv), (o)(2)(v), (o)(2)(vi), 

60.49Da(a), (s), (t), 60.50Da(b)(i), (e)(2), 60.51Da(a), (f), (h), (i), (j),and 

(k). 

D. Sulfur Dioxide (SO2)

1. Emission Limitations/Standards 

a. The Permittee shall not cause to be discharged into the 

atmosphere from Unit 3 stack, any gases which contain SO2 in 

excess of: 

(1) 520 nanograms per Joule (1.20 lb per million Btu) heat 

input and 10 percent of the potential combustion 

concentration (90 percent reduction) derived from 

combustion of coal; or [40 CFR §60.43 Da (a)(1)]
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(2) 30 percent of the potential combustion concentration (70 

percent reduction), when emissions are less than 260 

nanograms per Joule (0.60 lb per million Btu) heat input 

derived from combustion of coal. [40 CFR §60.43 Da (a)(2)] 

b. The Permittee shall not cause to be discharged into the 

atmosphere from Unit 4 stack, any gases which contain SO2 in 

excess of: [40 CFR §60.43 Da (i)(1)]

(1) 180 ng/J (1.4 lb/MWh) gross energy output on a 30-day 

rolling average basis; or 

(2) 5 percent of the potential combustion concentration (95 

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

c. The SO2 emission standard in Condition #s III.D.1.a and b shall 

apply at all times except during periods of startup or shutdown 

(as defined in Condition #s I.D.12 or 14), or periods when 

emergency conditions exist and the flue gas desulfurization 

system is malfunctioning. [40 CFR 60.48 Da (c)] 

d. Compliance with the SO2 emission standard in Conditions 

III.D.1.a and b shall be based upon a 30-day rolling average. 

[40 CFR 60.48 Da (e)] 

2. Air Pollution Control Requirements 

At all times when Unit 3 or Unit 4 is in operation, including periods of 

startup, shutdown, and malfunction as defined in Condition #s I.D.8, 12, 

and 14, the Permittee shall, to the extent practicable, maintain and

operate the dry flue gas desulfurization system in a manner consistent 

with good air pollution control practice for minimizing SO2 emissions.

[40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e] 

[Material Permit Conditions are defined by underline and italics] 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Monitoring for SO2

(1) The Permittee shall calibrate, maintain, and operate 

continuous emission monitoring systems (CEMS), and 

record the output of the system, for measuring SO2

emissions from Unit 3 and Unit 4. The monitoring 

systems shall measure SO2 emissions at both the inlet 

and outlet of the SO2 control device. [40 CFR 60.49 Da (b), 75.10 (a), and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

(2) As an alternative to the continuous SO2 emission 

monitoring system at the SO2 control device inlet in 

Condition III.D.3.a(1), an “as-fired” fuel monitoring 
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system (upstream of the coal pulverizers) meeting the 

requirements of EPA Reference Method 19 may be used 

to determine potential SO2emissions. 

[40 CFR 60.49 Da (b)(3)] 

(3) The CEMS used to measure SO2 emissions at the outlet 

of the SO2 control devices shall meet the applicable 

citing requirements of 40 CFR Part 60, Appendix B, and 

40 CFR Part 75, Appendix A. 

b. Compliance Determination Requirements for NSPS SO2 

Emission Standard 

For the purposes of demonstrating compliance with the SO2 

emission limitation in Condition III.D.1.a and b, the Permittee 

shall meet the following requirements: 

(1) Emission data from the continuous flow monitoring 

system, diluent CO2 or O2 monitoring systems, and SO2 

emission monitoring systems, required by Conditions 

III.K.1, III.K.2, and III.D.3.a(1), shall be used to 

demonstrate compliance. [40 CFR 60.50 Da (c)(5)] 

(2) For Unit 3, the Permittee shall obtain emission data for 

at least 18 hours in at least 22 out of 30 successive boiler 

operating days. For Unit 4, the Permittee shall obtain 

SO2 emission data for at least 90 percent of all operating 

hours for each 30 successive boiler operating days. If 

this minimum data requirement cannot be met with a 

continuous monitoring system, the Permittee shall 

supplement the emission data in accordance with the 

following: [40 CFR 60.49 Da (f)]

(a) Data obtained from other monitoring systems 

approved by the Director, or 

(b) For supplementary SO2 concentration data, data 

obtained from EPA Reference Method 6 or 6A 

or 6B or 6C, in accordance with the provisions 

of 40 CFR 60.49Da (h). 

(c) For supplementary diluent CO2 or O2 

concentration data, data obtained from EPA 

Reference Method 3 or 3A or 3B, in accordance 

with the provisions of 40 CFR 60.49Da (h). 

(3) Compliance with the SO2 emission limitations and 

percentage reduction requirements under Condition 

III.D.1.a and b is based on the average emission rate for 

30 successive operating days for Unit 3 and Unit 4. A 
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separate performance test is completed at the end of each 

boiler operating day after the initial performance test, 

and a new 30 day average emission rate and percent 

reduction is calculated to show compliance with the 

standards. Compliance with the applicable 30-day 

rolling average SO2 emission limitation for Unit 3 and 

Unit 4 is determined by calculating the arithmetic 

average of all hourly SO2 emission rates for the 30 

successive operating days, except for data obtained 

during startup, shutdown, or emergency conditions. 

Compliance with the percentage reduction requirement 

is determined based on the average inlet and outlet sulfur 

dioxide emission rates for the 30 successive operating 

days. [40 CFR 60.48 Da (e) and (g)] 

c. NSPS Requirements for CEMS 

The CEMS for SO2 emissions as required by Condition III.D.3.a 

shall meet the following requirements: 

(1) Calibration requirements at 40 CFR 60.13(d) 

(2) Operational requirements at 40 CFR 60.13(e) 

(3) Performance Specifications at 40 CFR Part 60, 

Appendix B 

(4) Quality Assurance Procedures at 40 CFR Part 60, 

Appendix F 

(5) Notification and recordkeeping requirements at 40 CFR 

60.7 

d. Acid Rain Program Requirements for Continuous Monitoring 

Systems 

The CEMS for SO2 emissions as required by Condition III.D.3.a 

shall meet all applicable requirements of 40 CFR Part 75. This 

shall include, but shall not be limited to, the following 

requirements: 

(1) 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures”. 

(2) 40 CFR Part 75, Appendix B, “Quality Assurance and 

Quality Control Procedure”. 

(3) Equipment performance requirements at 40 CFR 

75.10(b). 
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(4) Hourly operating requirements at 40 CFR 75.10(d). 

(5) Data reduction requirements at 40 CFR 75.10(d)(1). 

(6) Missing data substitution requirements at 40 CFR 

75.10(d)(3) and 40 CFR Part 75, Subpart D. 

(7) Certification and recertification requirements at 40 CFR 

75.20. 

e. The Permittee shall comply with all applicable recordkeeping 

and reporting requirements of 40 CFR Part 75, Subparts F and G, 

respectively. 

f. NSPS Subpart Da Reporting Requirements 

(1) For SO2, the performance test data from the performance 

test and from the performance evaluation of the 

continuous monitors are submitted to the Director and 

the Administrator. [40 CFR 60.51 Da (a)] 

(2) For SO2, the following is reported to the Director and the 

Administrator for each 24-hour period. 

[40 CFR 60.51 Da (b)] 

(a) Calendar date 

(b) The average SO2 emission rates (ng/J or 

lb/million Btu) for each 30 successive boiler 

operating days, ending with the last 30-day 

period in the quarter; reasons for noncompliance with the standard; and, description 

of corrective actions taken. 

(c) For complying with the percent reduction 

requirement, percent reduction of the potential 

reduction combustion concentration of SO2 for 

each 30 successive boiler operating days, ending 

with the last 30-day period in the quarter; 

reasons for non-compliance with the standard; 

and, description of corrective actions taken. 

(d) Identification of the boiler operating days for 

which pollutant or diluent data have not been 

obtained by an approved method for at least 75 

percent of operation of the facility; justification 

for not obtaining sufficient data; and description 

of corrective actions taken. 

(e) Identification of the times when emissions data 

have been excluded from the calculation of 
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average emission rates because of startup, 

shutdown (as defined in Condition #s I.D.12 and 

14), and emergency conditions, or other reasons, 

and justification for excluding data for reasons 

other than startup, shutdown, or emergency 

conditions. 

(f) Identification of “F” factor used for calculations, 

method of determination, and type of fuel 

combusted. 

(g) Identification of times when hourly averages 

have been obtained based on manual sampling 

methods. 

(h) Identification of the times when the pollutant 

concentration exceeded full span of the CMS. 

(i) Description of any modifications to the CMS 

which could affect the ability of the CMS to 

comply with Performance Specifications 2 or 3. 

(3) If the minimum quantity of emission data as required by 

Condition §60.49Da is not obtained for any 30 

successive boiler operating days, the following 

information obtained under the requirements of 

60.48Da(h) is reported to the Director and the 

Administrator for that 30 day period: [40 CFR 60.51Da (c)] 

(a) The number of hourly averages available for 

outlet emission rates (no) and inlet emission 

rates (ni) 

(b) The standard deviation of hourly averages for 

outlet emission rates (so) and inlet emission 

rates (si) as applicable. 

(c) The lower confidence limit for the mean outlet 

emission rate (Eo*) and the upper confidence 

limit for the mean inlet emission rate (Ei*) as 

applicable. 

(d) The applicable combustion concentration. 

(e) The ratio of the upper confidence limit for the 

mean outlet emission rate (Eo*) and the 

allowable emission rate (Estd) as applicable. 

(4) If the SO2 emission standard in Condition III.D.1.a is 

exceeded during emergency conditions because of 
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control system malfunction, the Permittee shall submit a 

signed statement: [40 CFR 60.51 Da (d)]

(a) Indicating if emergency conditions existed and 

requirements under 60.48Da(d) were met during 

each period, and 

(b) Listing the following information: 

(i) Time periods the emergency condition 

existed; 

(ii) Electrical output and demand on the 

Permittee’s electric utility system and 

the affected facility. 

(iii) Amount of power purchased from 

interconnected neighboring utility 

companies during the emergency period; 

(iv) Percent reduction in emissions achieved; 

(v) Atmospheric emission rate (ng/J) of the 

pollutant discharged; and 

(vi) Actions taken to correct control system 

malfunction. 

(5) If fuel pretreatment credit toward the SO2 emission 

standard in Condition III.D.1.a is claimed, the Permittee 

shall submit a signed statement: [40 CFR 60.51 Da (e)] 

(a) Indicating what percentage cleaning credit was 

taken for the calendar quarter, and whether the 

credit was determined in accordance with the 

provisions of 40 CFR 60.50Da and Method 19 

(appendix A of 40 CFR 60) ; and 

(b) Listing the quantity, heat content, and date each 

pretreated fuel shipment was received during the 

previous quarter; the name and location of the 

fuel pretreatment facility; and the total quantity 

and total heat content of all fuels received at the 

affected facility during the previous quarter. 

(6) For any periods for which SO2 emission data is not 

available, the Permittee shall submit a signed statement 

indicating if any changes were made in operation of the 

emission control system during the period of data 

unavailability. Operations of the control system and 
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Unit 3 and 4 during periods of data unavailability are to 

be compared with operation of the control system and 

affected facility before and following the period of data 

unavailability. [40 CFR 60.51 Da (f)] 

(7) The Permittee shall submit a signed statement indicating 

whether: [40 CFR 60.51 Da (h)]

(a) The required CEMS calibration, span, and drift 

checks or other periodic audits have or have not 

been performed as specified. 

(b) The data used to show compliance was or was 

not obtained in accordance with approved 

methods and procedures of 40 CFR 60 and is 

representative of plant performance. 

(c) The minimum data requirements have or have 

not been met; or, the minimum data 

requirements have not been met for errors that 

were unavoidable. 

(d) Compliance with the standards has or has not 

been achieved during the reporting period. 

(8) The Permittee shall submit the written reports required 

under this section and 40 CFR 60 Subpart A to the 

Director and the Administrator semiannually for each 

six-month period. All semiannual reports shall be 

postmarked by the 30th day following the end of each 

six-month period. [40 CFR 60.51 Da (j)]

(9) The Permittee may submit electronic quarterly reports 

for SO2 in lieu of submitting the written reports required 

under Condition III.D.3.(f)(2). The format of each 

quarterly electronic report shall be coordinated with the 

permitting authority (ADEQ). The electronic report(s) 

shall be submitted no later than 30 days after the end of 

the calendar quarter and shall be accompanied by a 

certification statement from the Permittee, indicating 

whether compliance with the applicable emission 

standards and minimum data requirements of 40 CFR 60 

Subpart Da was achieved during the reporting period. 

Before submitting reports in the electronic format, the 

Permittee shall coordinate with the Director to obtain 

their agreement to submit reports in this alternative 

format. [40 CFR 60.51 Da (k)] 

(10) The Permittee shall prepare and submit to the 

Administrator for approval a unit-specific monitoring 
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plan for each monitoring system, at least 45 days before 

commencing certification testing of the monitoring 

systems. The Permittee shall comply with the 

requirements in your plan. The plan must address the 

requirements of 40 CFR 60.49Da(s)(1) through (6). 

[40 CFR 60.49 Da (s)] 

4. Testing 

a. The Permittee shall perform performance tests to determine 

compliance with the SO2 emission limitation in Condition 

III.D.1.a. These performance tests shall be performed in 

accordance with 40 CFR 60.8. 

[40 CFR 60.8 and A.A.C. R18-2-306.A.3.a] 

b. Data from the CEMS for exhaust gas flow as required by 

Condition III.K.1, diluent concentration as required by Condition 

III.K.2, and SO2 emissions as required by Condition III.D.3.a 

shall be used during the performance tests to demonstrate 

compliance. [40 CFR 60.50 Da (c)(5)] 

c. The appropriate procedures in EPA Reference Method 19 shall 

be used to determine the SO2 emission rate and the percent 

reduction achieved by the SO2 emission control system. 

[40 CFR 60.50 Da (c)(3) and (c)(4)] 

d. As an alternative to the procedures in Condition III.D.4.b, a 

combination of an “as-fired” fuel monitor and emission rates 

measured after the SO2 emission control system, following the 

procedures in EPA Reference Method 19, may be used if the 

percent reduction is calculated using the average emission rate 

from the SO2 emission control system and the average SO2 input 

rate from the “as-fired” fuel analysis for 30 successive boiler 

operating days. [40 CFR 60.50 Da (c)(3)] 

e. Compliance is based on the average emission rate for 30 

successive operating days for each Unit 3 and Unit 4. 

Compliance is determined by calculating the arithmetic average 

of all hourly SO2 emission rates for the 30 successive operating 

days, except for data obtained during startup, shutdown, or 

malfunction. [40 CFR 60.48Da(g)]

f. The percent of potential SO2 emissions (%Ps) shall be computed 

using the equation set forth at 40 CFR 60.50Da(c)(1). 

[40 CFR 60.50 Da (c)(1)] 

g. During each performance test for Unit 3, the Permittee shall 

obtain emission data from each of the continuous SO2 and CO2

emission monitoring systems for at least 18 hours in at least 22 

out of 30 successive operating days. If this minimum data 

requirement is not met with a continuous monitoring system, the 
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Director may use the procedures in EPA Reference Method 19, 

Section 12.7, to determine compliance. 

[40 CFR 60.49 Da (f)(1) and (h)] 

h. During each performance test for Unit 4, the Permittee shall 

obtain emission data from each of the continuous SO2 and CO2

emission monitoring systems for at least 90 percent of all 

operating hours for each 30 successive boiler operating days. If 

this minimum data requirement is not met with a CEMS, the 

Director may use the procedures in EPA Reference Method 19, 

Section 12.7, to determine compliance. 

[40 CFR 60.49 Da (f)(2) and (h)] 

5. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with 40 CFR 60.43Da (a)(1), (2), & (i)(1), 60.48 Da (c), (e), 

& (g), 60.49 Da (b), (b)(3), (f), & (h), 60.50 Da(c)(1), (3), (4), & (5), 

60.51Da (a), (b), (c), (d), (e), (f), (h), (j), (k), and (s). 

E. Nitrogen Oxides (NOx)

1. Emission Limitations/Standards 

a. The Permittee shall not cause to be discharged into the 

atmosphere from Unit 3 stack, any gases which contain NOx 

(expressed as nitrogen dioxide) in excess of 200 nanograms per 

joule (1.6 pounds per megawatt-hour) gross energy output, based 

on a 30-day rolling average. [40 CFR 60.44 Da (d)(1)] 

b. The Permittee shall not cause to be discharged into the 

atmosphere from Unit 4 stack, any gases which contain NOx

(expressed as nitrogen dioxide) in excess of 130 nanograms per 

joule (1.0 pounds per megawatt-hour) gross energy output, based 

on a 30-day rolling average. [40 CFR 60.44 Da (e)(1)] 

c. The NOx emission standard in Conditions III.E.1.a and b shall 

apply at all times except during periods of startup, shutdown, or 

malfunction (as defined in Condition #s I.D.8, 12, and 14). 

[40 CFR 60.48 Da (c)] 

2. Air Pollution Control Requirements 

At all times when Unit 3 or Unit 4 is in operation, including periods of 

startup, shutdown, and malfunction as defined in Condition #s I.D.8, 12, 

and 14, the Permittee shall, to the extent practicable, maintain and

operate the SCR system in a manner consistent with good air pollution 

control practice for minimizing NOx emissions. [40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Conditions are defined by underline and italics] 
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3. Monitoring/Recordkeeping/Reporting Requirements 

a. Monitoring for NOx

(1) The Permittee shall calibrate, maintain, and operate

continuous monitoring systems, and record the output of 

the systems, for measuring NOx emissions discharged to 

the atmosphere from Unit 3 and Unit 4.

[40 CFR 60.49 Da (c)(1), 75.10(a), and A.A.C. R18-2-331.a.3.c] 

[Material Permit Conditions are defined by underline and italics] 

(2) The continuous monitoring system used to meet the 

requirements of 40 CFR Part 75 may be used to meet the 

requirements of 40 CFR Part 60, Subpart Da, 

§60.49Da(c)(1). The Permittee shall meet the 

requirements of 40 CFR 60.50Da. Data reported to meet 

the requirements of 40 CFR 60.50Da shall not include 

data substituted using the missing data procedures in 

Subpart D of 40 CFR Part 75, nor shall the data have 

been bias adjusted according to the procedures of 40 

CFR Part 75. [40 CFR 60.49 Da (c)(2)]

b. Compliance Determination Requirements for NSPS NOx

Emission Standard 

For the purposes of demonstrating compliance with the NOx

emission limitation in Condition III.E.1.a, the Permittee shall 

meet the following requirements: 

(1) Emission data from the continuous flow monitoring 

systems, wattmeters, and continuous NOx emission 

monitoring systems required by Conditions III.K.1, 

III.K.4, and III.E.3.a respectively, shall be used to 

demonstrate compliance. [40 CFR 60.50 Da (d)(2)]

(2) For Unit 3, the Permittee shall obtain emission data from 

the continuous NOx emission monitoring systems for at 

least 18 hours in at least 22 out of each 30 successive 

operating days. [40 CFR 60.49 Da (f)(1)]

(3) For Unit 4, the Permittee shall obtain NOx emission data 

for at least 90 percent of all operating hours for each 30 

successive boiler operating days. [40 CFR 60.49 Da (f)(2)]

(4) If this minimum data requirement cannot be met with a 

continuous monitoring system, the Permittee shall 

supplement the emission data in accordance with the 

following: [40 CFR 60.49 Da (f)] 

(a) Data obtained from other monitoring systems 

approved by the Director, or 
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(b) For supplementary NOx concentration data, data 

obtained from EPA Reference Method 7 or 7A 

or 7C or 7E, in accordance with the provisions 

of 40 CFR 60. 49Da (h). 

(5) The NOx emission rate shall be calculated by 

multiplying the average hourly NOx output concentration 

by the average hourly flow rate and divided by the 

average hourly gross electrical output. [40 CFR 60.48 Da (i)] 

(6) Compliance with the NOx emission limitation under 

Condition III.E.1.a and b is based on the average 

emission rate for 30 successive operating days for Unit 3 

and Unit 4. Compliance is determined by calculating the 

arithmetic average of all hourly NOx emission rates for 

the 30 successive operating days, except for data 

obtained during startup, shutdown, or malfunction (as 

defined in Condition #s I.D.8, 12, and 14). A separate 

performance test is completed at the end of each 

operating day and a new 30-day average nitrogen oxides 

emission rate is calculated to show compliance with the 

emission standard. [40 CFR 60.48 Da (e) and (g)] 

c. NSPS Requirements for Continuous Monitoring Systems 

The continuous monitoring systems for NOx emissions as 

required by Condition III.E.3.a (except as provided by Condition 

III.E.3.a.(2)) shall meet the following requirements: 

(1) Calibration requirements at 40 CFR 60.13(d) 

(2) Operational requirements at 40 CFR 60.13(e) 

(3) Performance Specifications at 40 CFR Part 60, 

Appendix B 

(4) Quality Assurance Procedures at 40 CFR Part 60, 

Appendix F 

(5) Notification and recordkeeping requirements at 40 CFR 

60.7. 

d. Acid Rain Program Requirements for Continuous Monitoring 

Systems 

The continuous monitoring systems for NOx emissions as 

required by Condition III.E.3.a shall meet all applicable 

requirements at 40 CFR Part 75. This shall include, but shall not 

be limited to, the following requirements: 
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(1) 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures”. 

(2) 40 CFR Part 75, Appendix B, “Quality Assurance and 

Quality Control Procedure”. 

(3) Equipment performance requirements at 40 CFR 

75.10(b). 

(4) Hourly operating requirements at 40 CFR 75.10(d). 

(5) Data reduction requirements at 40 CFR 75.10(d)(1). 

(6) Missing data substitution requirements at 40 CFR 

75.10(d)(3) and 40 CFR Part 75, Subpart D. 

(7) Certification and recertification requirements at 40 CFR 

75.20. 

e. The Permittee shall comply with all applicable recordkeeping 

and reporting requirements of 40 CFR Part 75, Subparts F and G, 

respectively. 

f. NSPS Reporting Requirements 

(1) The performance test data from the performance 

evaluation of the continuous monitors are submitted to 

the Director and the Administrator.[40 CFR 60.51Da (a)] 

(2) The following information is reported to the Director 

and the Administrator for each 24-hour period. 

[40 CFR 60.51 Da (b)] 

(a) Calendar date 

(b) The average NOx emission rates (ng/J or 

lb/million Btu) for each 30 successive boiler 

operating days, ending with the last 30-day 

period in the quarter; reasons for noncompliance with the standard; and, description 

of corrective actions taken. 

(c) Identification of the boiler operating days for 

which pollutant or diluent data have not been 

obtained by an approved method for at least 18 

hours of operation of the facility; justification 

for not obtaining sufficient data; and description 

of corrective actions taken. 

(d) Identification of the times when emissions data 

have been excluded from the calculation of 
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average emission rates because of startup, 

shutdown, malfunction, or other reasons, and 

justification for excluding data for reasons other 

than startup, shutdown, malfunction (as defined 

in Condition #s I.D.8, 12, and 14), or emergency 

conditions. 

(e) Identification of “F” factor used for calculations, 

method of determination, and type of fuel 

combusted. 

(f) Identification of times when hourly averages 

have been obtained based on manual sampling 

methods. 

(g) Identification of the times when the pollutant 

concentration exceeded full span of the 

continuous monitoring system. 

(h) Description of any modifications to the 

continuous monitoring system which could 

affect the ability of the continuous monitoring 

system to comply with Performance 

Specifications 2 or 3. 

(3) If the minimum quantity of emission data as required by 

40 CFR 60.49Da is not obtained for any 30 successive 

boiler operating days, the following information 

obtained under the requirements of §60.48a(h) is 

reported to the Department and the Administrator for 

that 30 day period: [40 CFR 60.51 Da (c)] 

(a) The number of hourly averages available for 

outlet emission rates (no) and inlet emission 

rates (ni) 

(b) The standard deviation of hourly averages for 

outlet emission rates (so) and inlet emission 

rates (si) as applicable. 

(c) The lower confidence limit for the mean outlet 

emission rate (Eo*) and the upper confidence 

limit for the mean inlet emission rate (Ei*) as 

applicable. 

(d) The applicable combustion concentration. 

(e) The ratio of the upper confidence limit for the 

mean outlet emission rate (Eo*) and the 

allowable emission rate (Estd) as applicable. 
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(4) For any periods for which NOx emissions data is not 

available, the Permittee shall submit a signed statement 

indicating if any changes were made in operation of the 

emission control system during the period of data 

unavailability. Operations of the control system and 

Unit 3 and 4 during periods of data unavailability are to 

be compared with operation of the control system and 

affected facility before and following the period of data 

unavailability. [40 CFR 60.51 Da (f)] 

(5) The Permittee shall submit a signed statement indicating 

whether: [40 CFR 60.51 Da (h)] 

(a) The required continuous monitoring system 

calibration, span, and drift checks or other 

periodic audits have or have not been performed 

as specified. 

(b) The data used to show compliance was or was 

not obtained in accordance with approved 

methods and procedures of 40 CFR 60Da and is 

representative of plant performance. 

(c) The minimum data requirements have or have 

not been met; or, the minimum data 

requirements have not been met for errors that 

were unavoidable. 

(d) Compliance with the standards has or has not 

been achieved during the reporting period. 

(6) The Permittee shall submit the written reports required 

under this section and 40 CFR 60 Subpart A to the 

Director and the Administrator semiannually for each 

six-month period. All semiannual reports shall be 

postmarked by the 30th day following the end of each 

six-month period. [40 CFR 60.51 Da (j)]

(7) The Permittee may submit electronic quarterly reports 

for NOx in lieu of submitting the written reports required 

under Condition III.E.3.(f)(2). The format of each 

quarterly electronic report shall be coordinated with the 

Director. The electronic report(s) shall be submitted no 

later than 30 days after the end of the calendar quarter 

and shall be accompanied by a certification statement 

from the Permittee, indicating whether compliance with 

the applicable emission standards and minimum data 

requirements of 40 CFR 60 Subpart Da was achieved 

during the reporting period. Before submitting reports in 

the electronic format, the Permittee shall coordinate with 
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the Director to obtain their agreement to submit reports 

in this alternative format. [40 CFR 60.51 Da (k)] 

(8) The Permittee shall prepare and submit to the 

Administrator for approval a unit-specific monitoring 

plan for each monitoring system, at least 45 days before 

commencing certification testing of the monitoring 

systems. The owner or operator shall comply with the 

requirements in your plan. The plan must address the 

requirements of 40 CFR 60.49Da(s)(1) through (6). 

[40 CFR 60.49 Da (s)] 

4. Testing 

a. The Permittee shall perform performance tests to determine 

compliance with the NOx emission limitation in Condition 

III.E.1.a and b. These performance tests shall be performed in 

accordance with 40 CFR 60.8. 

[40 CFR 60.8 and A.A.C. R18-2-306.A.3.a] 

b. Data from the CEMS for exhaust gas flow as required by 

Condition III.K.1, wattmeters as required by Condition III.K.4, 

and NOx emissions as required by Condition III.E.3.a shall be 

used during the performance tests to demonstrate compliance. [40 CFR 60.50 Da (d)(2)] 

c. The NOx emission rate shall be calculated by multiplying the 

average hourly NOx output concentration by the average hourly 

flow rate and divided by the average hourly gross electrical 

output. [40 CFR 60.48 Da (i)] 

d. Compliance is based on the average emission rate for 30 

successive operating days for each Unit 3 and Unit 4. 

Compliance is determined by calculating the arithmetic average 

of all hourly NOx emission rates for the 30 successive operating 

days, except for data obtained during startup, shutdown, or 

malfunction. [40 CFR 60.48 Da (g)]

e. During each performance test, for Unit 3, the Permittee shall 

obtain emission data from the continuous NOx emission 

monitoring system for at least 18 hours in at least 22 out of 30 

successive operating days. For Unit 4, the Permittee shall obtain 

emission data for at least 90 percent of all operating hours for 

each 30 successive boiler operating days. If this minimum data 

requirement is not met with a continuous monitoring system, the 

Director may use the procedures in EPA Reference Method 19, 

Section 12.7, to determine compliance. [40 CFR 60.49 Da (f) and (h)] 

5. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with 40 CFR 60.44Da (d)(1) & (e)(1), 60.48 Da (c), (e), (g), 
Permit #53418 69 of 131 August 15, 2012 

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& (i), 60.49 Da (c)(1) & (2), (e), & (g), 60.50 Da (d)(2), 60.51 Da (a), 

(b), (c), (f), (h), (j), (k), and (s). 

F. Carbon Monoxide (CO) 

1. Emission Limitations/Standard 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 3 or Unit 4 any gases which 

contain CO in excess of 0.15 lb per million Btu heat input 

derived from combustion of fuel, based on a 30-day rolling 

average. [A.A.C. R18-2-406.A.4] 

b. The CO emission standard in Condition III.F.1.a shall apply at 

all times except during periods of startup, shutdown, or 

malfunction (as defined in Condition #s I.D.8, 12, and 14). 

[A.A.C. R18-2-406.A.4] 

2. Monitoring/Recordkeeping/Reporting Requirements 

a. Monitoring for CO 

(1) The Permittee shall, calibrate, maintain, and operate 

CEMS, and record the output of the systems, for 

measuring CO emissions discharged to the atmosphere 

from Unit 3 and Unit 4.

[A.A.C. R18-2-331.A.3.c and -306.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

(2) The CEMS for CO shall meet the following 

requirements: [A.A.C. R18-2-331.A.3.c and -306.A.3.c]

[Material Permit Conditions are defined by underline and italics] 

(a) Calibration requirements at 40 CFR 60.13(d).

(b) Operational requirements at 40 CFR 60.13(e). 

(c) Performance Specifications at 40 CFR Part 60, 

Appendix B. 

(d) Quality Assurance Procedures at 40 CFR Part 

60, Appendix F.

b. Compliance Determination Requirements for CO Emission 

Standard 

The Permittee shall use the following procedures to demonstrate 

compliance with the CO emission limitation in Condition 

III.F.1.a. [A.A.C. R18-2-306.A.3.c] 

(1) The Permittee shall use data from the continuous flow 
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monitoring system, diluent CO2 or O2 monitoring 

systems, and CO emission monitoring systems as 

required by Conditions III.K.1, III.K.2, and III.F.2.a 

respectively. 

(2) The requirements of Condition III.F.2.b shall apply only 

to Unit 3 and Unit 4 and shall apply separately to Unit 3 

and Unit 4. 

(3) Compliance with the CO emission limitation under 

Condition III.F.1.a is based on the average emission rate 

for 30 successive calendar days for Unit 3 and Unit 4. 

Compliance is determined by calculating the arithmetic 

average of all hourly CO emission rates for the 30 

successive calendar days, except for data obtained 

during startup, shutdown (as defined in Condition #s 

I.D.8, and 12), or emergency conditions. A separate 

performance test is completed at the end of each 

calendar day, and a new 30-day average CO2 emission 

rate is calculated to show compliance with the emission 

standard. 

(4) Each calendar day, for which the 30-day rolling average 

CO emission rate exceeds the CO emission limitation in 

Condition III.F.1.a, shall constitute a period of excess 

emissions. 

(5) For each continuous monitoring system for CO, the 

Permittee shall submit a Quality Assurance/Quality 

Control Plan to the Director at least 30 days prior to the 

start-up of the monitoring system. When approved by 

the Director, this plan shall be implemented. 

3. Testing 

a. The Permittee shall perform annual performance tests to 

determine compliance with the CO emission limitation in 

Condition III.F.1.a. [A.A.C. R18-2-406.A.4]

b. Data from the continuous monitoring systems for exhaust gas 

flow as required by Condition III.K.1, diluent concentration as 

required by Condition III.K.3, and CO emissions as required by 

Condition III.F.2.a shall be used during the performance tests to 

demonstrate compliance. [A.A.C. R18-2-406.A.4] 

c. The appropriate procedures in EPA Reference Method 19 shall 

be used to determine the CO emission rate. As Method 19 does 

not provide conversion factors for CO, a conversion factor of 

7.27x10-8 shall be used to convert parts per million (ppm) to 

pounds per standard cubic foot (lb/scf). [A.A.C. R18-2-406.A.4] 
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G. Volatile Organic Compounds (VOC) 

1. Emission Limitations/Standards 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 3 or Unit 4 any gases which 

contains VOCs, expressed as propane, in excess of 0.06 lb per 

ton of coal combusted. Compliance with this emission limit 

shall be determined using a three-hour averaging period. 

[A.A.C. R18-2-406.A.4] 

b. The VOCs emission standard in Condition III.G.1.a shall apply 

at all times except during periods of startup, shutdown, or 

malfunction (Condition #s I.D.8, 12, and 14). 

[A.A.C. R18-2-406.A.4] 

2. Testing 

a. The Permittee shall perform performance tests, within 12 months 

of issuance of this permit, to determine compliance with the 

VOC emission limitation in Condition III.G.1.a. 

[A.A.C. R18-2-306.A.3.c] 

b. If the results of any performance test show that the VOC 

emissions are less than 50 percent of the specified emission 

limitation in Condition III.G.1.a, no additional testing shall be 

required for that steam generating unit during the term of this 

permit. If the results of the performance test show that the VOC 

emissions are greater than or equal to 50 percent of the specified 

emission limitation in Condition III.G.1.a, annual testing shall be 

required for that steam generating unit. 

c. The performance test for VOCs shall be performed using EPA 

Reference Method 18 or 25A. [A.A.C. R18-2-406.A.4] 

H. Hydrogen Fluoride (HF) 

1. Emission Limitations/Standards [A.A.C. R18-2-302.D and -406.A.4] 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stack of Unit 3 or Unit 4 any gases which 

contain HF in excess of 0.00044 lb per million Btu heat input 

derived from combustion of fuel. Compliance with this emission 

limit shall be determined using a three-hour averaging period. 

b. The HF emission standard in Condition III.H.1.a shall apply at 

all times except during periods of startup, shutdown, or 

malfunction (as defined in Condition #s I.D.8, 12, and 14). 
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2. Testing [A.A.C. R18-2-302.D, -312, and 406.A.4]

a. The Permittee shall perform performance tests, within 12 months 

of issuance of this permit, to determine compliance with the HF 

emission limitation in Condition III.H.1.a. 

b. If the results of any performance test show that the HF emissions 

are less than 50 percent of the specified emission limitation in 

Condition III.H.1.a, no additional testing shall be required for 

that steam generating unit during the term of this permit. If the 

results of the performance test show that the HF emissions are 

greater than or equal to 50 percent of the specified emission 

limitation in Condition III.H.1.a, annual testing shall be required 

for that steam generating unit. 

c. The performance test for HF shall be performed using EPA 

Reference Method 26A. 

I. Lead (Pb) 

1. Emission Limitations/Standards 

The Permittee shall not cause to be discharged into the atmosphere from 

the stacks of Unit 3 or Unit 4 any gases which contain Pb in excess of 

0.000016 lb per million Btu heat input derived from combustion of fuel. 

Compliance with this emission limit shall be determined using a threehour averaging period. [A.A.C. R18-2-306.02] 

2. Testing 

a. The Permittee shall perform performance tests, within 12 months 

of issuance of this permit, to determine compliance with the Pb 

emission limitation in Condition III.I.1.a. 

b. If the results of any performance test show that the Pb emissions 

are less than 50 percent of the specified emission limitation in 

Condition III.I.1.a, no additional testing shall be required for that 

steam generating unit during the term of this permit. If the 

results of the performance test show that the Pb emissions are 

greater than or equal to 50 percent of the specified emission 

limitation in Condition III.I.1.a, annual testing shall be required 

for that steam generating unit. 

c. Each performance test for lead shall be performed using EPA 

Reference Method 12 or 29. [A.A.C. R18-2-306.A.2] 
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J Mercury Emission Standard 

1. Emission Limitations/Standards 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stack of Unit 3 and Unit 4 any gases which 

contain mercury in excess of 0.0000069 lb per million Btu heat 

input derived from combustion of fuel. Compliance with this 

emission limit shall be determined using a three-hour averaging 

period. [40 CFR 63.43(g)(1) and A.A.C. R18-2-302.D]

b. The mercury emission standard in Condition III.J.1.a shall apply 

at all times except during periods of startup, shutdown, or 

malfunction (as defined in Condition #s I.D.8, 12, and 14). 

[40 CFR 63.6 (f) and A.A.C. R18-2-302.D] 

2. Testing [A.A.C. R18-2-302.D]

a. The Permittee shall perform annual performance tests on Unit 3 

and Unit 4 to determine compliance with the mercury emission 

limitation in Condition III.J.1.a. [40 CFR 63.43 (g)(2)(iv)] 

b. Each performance test for mercury shall be performed using 

EPA Reference Method 29 or Method 30B. [40 CFR 63.7(e)] 

c. The Permittee shall develop and submit to the Director a sitespecific test plan in accordance with the provisions of 40 CFR 

63.7(b) at least 60 days prior to each scheduled performance test 

required by Condition III.J.2.a. [40 CFR 63.7(b)] 

K. Additional Monitoring, Recordkeeping, and Reporting Requirements 

1. Monitoring of Flow 

a. The Permittee shall certify, maintain, and operate continuous 

flow monitoring systems, and record the output of the systems, 

for measuring the flow of exhaust gases discharged to the 

atmosphere from Unit 3 and Unit 4.

[40 CFR 60.49 Da (a)(l), 75.10(a), and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

b. Data from continuous flow monitoring systems certified 

according to the requirements of 40 CFR 75.20, meeting the 

applicable quality control and quality assurance requirements of 

40 CFR 75.21, and validated according to 40 CFR 75.23, may be 

used to satisfy the requirements of 40 CFR 60.49Da(l). 

[40 CFR 60.49 Da (m)] 

2. Monitoring for CO2

The Permittee shall, calibrate, maintain, and operate a continuous 

monitoring system, and record the output of the system, for measuring 
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CO2 emissions discharged to the atmosphere from Unit 3 and Unit 4.

[40 CFR 75.10(a) and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

3. Monitoring for Diluent Concentration 

a. The Permittee shall, calibrate, maintain, and operate continuous

monitoring systems, and record the output of the systems, for 

measuring diluent CO2 or O2 concentration in the exhaust gas 

streams from Unit 3 and Unit 4. The monitoring systems shall 

measure CO2 or O2 concentration at both the inlet and outlet of 

the SO2 control device unless the Permittee elects to monitor for 

inlet SO2 using the alternative method described in Condition 

III.D.3.a.(2). [40 CFR 60.49 Da (d) and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

b. The CO2 continuous monitoring system required by Condition 

III.K.2 may be used to satisfy the requirement for monitoring of 

diluent concentration at the outlet of the SO2 control device, 

provided that it meets the applicable siting requirements of 40 

CFR Part 60, Appendix B. [40 CFR 60.49 Da (d)]

4. Monitoring of Electrical Output 

The Permittee shall calibrate, maintain, and operate the wattmeters, 

utilize the wattmeters to measure the gross electrical output in megawatthours from Unit 3 and Unit 4 on a continuous basis, and record the 

output of the wattmeters. [40 CFR 60.49 Da (k) and A.A.C. R18-2-331.A.3.c] 

[Material Permit Conditions are defined by underline and italics] 

5. Measurement of Heat Input 

The Permittee shall determine and record the heat input to Unit 3 and 

Unit 4 for every hour or part of an hour any fuel is combusted following 

the procedures in 40 CFR Part 75, Appendix F. 

[40 CFR 60.49 Da (d) and 75.10(a)] 

6. NSPS Requirements for Continuous Monitoring Systems 

The continuous monitoring systems for exhaust gas flow required by 

Condition III.K.1 (except as provided by Condition III.K.1.b) and diluent 

concentration required by Condition III.K.3 shall meet the following 

requirements: 

a. Calibration requirements at 40 CFR 60.13(d) 

b. Operational requirements at 40 CFR 60.13(e) 

c. Performance Specifications at 40 CFR Part 60, Appendix B 

d. Quality Assurance Procedures at 40 CFR Part 60, Appendix F 
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7. Acid Rain Program Requirements for Continuous Monitoring Systems 

The continuous monitoring systems for exhaust gas flow required by 

Condition III.K.1 and CO2 emissions required by Condition III.K.2 shall 

meet all applicable requirements at 40 CFR Part 75. This shall include, 

but not be limited to, the following requirements: 

a. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures.” 

b. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure.” 

c. Equipment performance requirements at 40 CFR 75.10(b). 

d. Hourly operating requirements at 40 CFR 75.10(d). 

e. Data reduction requirements at 40 CFR 75.10(d)(1). 

f. Missing data substitution requirements at 40 CFR 75.10(d)(3) 

and 40 CFR Part 75, Subpart D. 

g. Certification and recertification requirements at 40 CFR 75.20. 

8. The Permittee shall comply with all applicable recordkeeping and 

reporting requirements of 40 CFR Part 75, Subparts F and G, 

respectively. 

9. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with 40 CFR 60.49 Da (a)(1), (d), (k), and (m). 

IV. UNIT 1, UNIT 2, UNIT 3, AND UNIT 4 (P1, P2, P3, AND P4) (COMBINED 

LIMITS)

A. Applicability 

This Section applies to Unit 1, Unit 2, Unit 3, and Unit 4 as described in 

Condition I.D.18 and Equipment List, Attachment “C”. 

B. Sulfur Dioxide (SO2)

1. Emission Limitations/Standards [A.A.C. R18-2-406.H and 40 CFR 70.8(c)(4)] 

a. The Permittee shall not cause to be discharged into the 

atmosphere from the stacks of Unit 1, Unit 2, Unit 3, and Unit 4, 

in total, any gases which contain SO2 in excess of 8,448 lbs per 
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hour. Compliance with this emission limit shall be determined 

on a rolling 3-hour average basis. 

b. Total emissions of SO2 from Unit 1, Unit 2, Unit 3, and Unit 4 

shall not exceed 10,800 tons per year. 

c. Compliance with the emission limit in Condition IV.B.1.b shall 

be determined on both a calendar-year total and a 12-month 

rolling total basis. 

2. Monitoring/Recordkeeping/Reporting Requirements 

a. The Permittee shall use the following procedure to demonstrate 

compliance with the hourly SO2 emission limitation in Condition 

IV.B.1.a: [A.A.C. R18-2-306.A.3.c] 

(1) The Permittee shall use the data from the continuous SO2

emission monitoring systems for Unit 1 and Unit 2 as 

required by Condition II.D.3, the continuous flow 

monitoring systems for Unit 1 and Unit 2 as required by 

40 CFR Part 75, and the flow monitoring systems and 

continuous SO2 emission monitoring systems for Unit 3 

and Unit 4 as required by Condition #s III.K.1 and 

III.D.3.a respectively. 

(2) For each one-hour period, the Permittee shall record the 

hourly mass emissions (in lbs) for each steam generating 

unit that operated during the hour. 

(3) For each one-hour period, the Permittee shall calculate 

and record the three-hour average mass emission rate for 

each steam generating unit that operated during the hour. 

The three-hour average mass emission rate shall be 

calculated as the sum of the mass emissions for the 

subject hour, plus the mass emissions for the two 

preceding hours, divided by three. The three-hour 

average mass emission rate shall be expressed in lbs per 

hour. 

(4) For each one-hour period, the Permittee shall calculate 

and record the combined three-hour average mass 

emission rate for Unit 1, Unit 2, Unit 3, and Unit 4. The 

combined three-hour average mass emission rate shall be 

calculated as the sum of the three-hour average mass 

emission rates for all steam generating units that 

operated during the three-hour period. The combined 

three-hour average mass emission rate shall be expressed 

in lbs per hour. 

(5) Each one-hour period for which the combined three-hour 
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average mass emission rate calculated in Condition 

IV.B.2.a(4) exceeds the SO2 emission limitation in 

Condition IV.B.1.a shall constitute a period of excess 

emissions. 

b. The Permittee shall use the following procedure to demonstrate 

compliance with the yearly SO2 emission limitations in 

Condition IV.B.1.b. [A.A.C. R18-2-304.E.9] 

(1) For each calendar month, the Permittee shall calculate 

and record the monthly mass emissions for each steam 

generating unit that operated during the calendar month. 

The monthly mass emissions shall be calculated as the 

sum of all hourly mass emissions recorded during the 

month pursuant to Condition IV.B.2.a(2) and shall be 

expressed in tons. 

(2) For each calendar month, the Permittee shall calculate 

and record the combined monthly mass emissions for 

Unit 1, Unit 2, Unit 3, and Unit 4. The combined 

monthly mass emissions shall be calculated as the sum 

of the monthly mass emissions for all steam generating 

units that operated during the calendar month. The 

combined monthly mass emissions shall be expressed in 

tons. 

(3) For each calendar month, the Permittee shall calculate 

and record the combined annual mass emissions for Unit 

1, Unit 2, Unit 3, and Unit 4. The combined annual 

mass emissions shall be calculated as the sum of the 

combined monthly mass emissions for the subject 

month, plus the combined monthly mass emissions for 

the eleven preceding months. The combined annual 

mass emissions shall be expressed in tons. 

(4) The data recorded under Conditions III.B.2.b (1) to (3) 

shall be available for inspection by the fifth working day 

of the month following the month for which the 

calculation is being made. 

(5) For each continuous monitoring system for SO2

emissions, the Permittee shall submit a Quality 

Assurance/Quality Control Plan to the Director and the 

Administrator at least 30 days prior to the start-up of the 

monitoring system. Each Plan shall include procedures 

for dealing with data gaps using the procedures 

contained in 40 CFR Part 75, Subpart D. When 

approved by the Director, this plan shall be 

implemented. 
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(6) Combined mass emissions that exceed the rolling 12-

month SO2 emission limitation in Condition IV.B.1.b 

shall constitute a violation for each day of the preceding 

month for each electric generating unit in operation on 

that day. 

(7) Combined mass emissions that exceed the calendar-year 

sulfur dioxide emission limitation in Condition IV.B.1.b 

shall constitute a violation for each day of the preceding 

calendar year for each electric generating unit in 

operation on that day. 

(8) A violation under Conditions IV.B.2.b (6) and (7) that 

occurs on the same day at the same unit shall count as a 

single violation. 

C. Nitrogen Oxides (NOx)

1. Emission Limitations/Standards [A.A.C. R18-2-406.H and 40 CFR 70.8(c)(4)] 

a. Total emission of NOx from Unit 1, Unit 2, Unit 3, and Unit 4 

shall not exceed 9,600 tons per year. 

 b. Compliance with the emission limit in Condition IV.C.1.a shall 

be determined on both a calendar-year total and a 12-month 

rolling total basis. 

2. Monitoring/Recordkeeping/Reporting Requirements 

The Permittee shall use the following procedure to demonstrate 

compliance with the NOx emission limitation in Condition IV.C.1.a: 

[A.A.C. R18-2-306.A.3.c] 

a. The Permittee shall use the data from the continuous NOx

emission monitoring systems for Unit 1 and Unit 2 as required 

by Condition II.F.2, the continuous flow monitoring systems for 

Unit 1 and Unit 2 as required by 40 CFR Part 75, and the flow 

monitoring systems and continuous nitrogen oxides emission 

monitoring systems for Unit 3 and Unit 4 as required by 

Conditions III.K.1 and III.F.3. 

b. For each calendar month, the Permittee shall calculate and record 

the monthly mass emissions for each steam generating unit that 

operated during the calendar month. The monthly mass 

emissions shall be expressed in tons. 

c. For each calendar month, the Permittee shall calculate and record 

the combined monthly mass emissions for Unit 1, Unit 2, Unit 3, 

and Unit 4. The combined monthly mass emissions shall be 

calculated as the sum of the monthly mass emissions for all 
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steam generating units that operated during the calendar month. 

The combined monthly mass emissions shall be expressed in 

tons. 

d. For each calendar month, the Permittee shall calculate and record 

the combined annual mass emissions for Unit 1, Unit 2, Unit 3, 

and Unit 4. The combined annual mass emissions shall be 

calculated as the sum of the combined monthly mass emissions 

for the subject month, plus the combined monthly mass 

emissions for the eleven preceding months. The combined 

annual mass emissions shall be expressed in tons. 

e. The data recorded under Condition #s IV.C.2.b and d shall be 

available for inspection by the fifth working day of the month 

following the month for which the calculation is being made. 

f. For each continuous monitoring system for NOx emissions, the 

Permittee shall submit a Quality Assurance/Quality Control Plan 

to the Director at least 30 days prior to the start-up of the 

monitoring system. Each plan shall include procedures for 

dealing with data gaps using the procedures contained in 40 CFR 

Part 75, Subpart D. When approved by the Director, this plan 

shall be implemented. 

g. Combined mass emissions that exceed the rolling 12-month NOx

emission limitation in Condition IV.C.1.a shall constitute a 

violation for each day of the preceding month for each electric 

generating unit in operation on that day. 

h. Combined mass emissions that exceed the calendar-year NOx

emission limitation in Condition IV.C.1.a shall constitute a 

violation for each day of the preceding calendar year for each 

electric generating unit in operation on that day. 

i. A violation under Conditions IV.C.2.g and h that occurs on the 

same day at the same unit shall count as a single violation. 

D. Sulfuric Acid Mist (H2SO4)

1. Emission Limitations/Standards [A.A.C. R18-2-306.02] 

The Permittee shall not cause to be discharged into the atmosphere from 

the stacks of Unit 1, Unit 2, Unit 3, and Unit 4, in total, any gases which 

contain H2SO4 mist in excess of 211 tons per year. Compliance with this 

emission cap shall be determined on a 12-month rolling total basis. 

2. Monitoring/Recordkeeping/Reporting Requirements 

a. Compliance Determination Requirements for H2SO4 Mist 

Emission Cap 
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The Permittee shall use the following procedures to demonstrate 

compliance with the H2SO4 mist emission limitation in Condition 

IV.D.1: [A.A.C. R18-2-306.A.3.c] 

(1) For each calendar month, the Permittee shall calculate 

and record the monthly mass emissions of H2SO4 mist 

for each steam generating unit that operated during the 

calendar month. The monthly mass emissions of H2SO4 

mist for each unit shall be calculated as the product of 

the SO2 monthly mass emissions for that unit as 

calculated under Condition IV.B.2.b and the sulfur 

compound emission ratio for that unit. The monthly 

mass emissions of H2SO4 mist for each steam generating 

unit shall be expressed in tons. 

(a) The sulfur compound emission ratio for Unit 1 

and Unit 2 is 0.01127. 

(b) The sulfur compound emission ratio for Unit 3 is 

0.0408 and for Unit 4 is 0.025. 

(2) For each calendar month, the Permittee shall calculate 

and record the combined monthly mass emissions of 

sulfuric acid mist for Unit 1, Unit 2, Unit 3, and Unit 4. 

The combined monthly mass emissions of H2SO4 shall 

be calculated as the sum of the monthly mass emissions 

of H2SO4 mist for all steam generating units that 

operated during the calendar month. The combined 

monthly mass emissions of H2SO4 mist shall be 

expressed in tons. 

(3) For each calendar month, the Permittee shall calculate 

and record the combined annual mass emissions of 

H2SO4 mist for Unit 1, Unit 2, Unit 3, and Unit 4. The 

combined annual mass emissions of H2SO4 mist shall be 

calculated as the sum of the combined monthly mass 

emissions of H2SO4 mist for the subject month, plus the 

combined monthly mass emissions of H2SO4 mist for the 

eleven preceding months. The combined annual mass 

emissions of H2SO4 mist shall be expressed in tons. 

(4) The data recorded under Conditions IV.D.2.a (1) through 

(3) shall be available for inspection by the fifth working 

day of the month following the month for which the 

calculation is being made. 

(5) Each calendar month for which the combined annual 

mass emissions of H2SO4 mist exceeds the H2SO4 mist 

emission limitation in Condition IV.D.1 shall constitute 

a period of excess emissions. 
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E. Mercury [State Enforceable Only] [Consent Order #A-16-09]

1. The State mercury standard set forth in A.A.C. R18-2-734 shall not apply 

to the Permittee until December 31, 2016. 

2. The Permittee shall implement the Operation and Maintenance (O&M) 

plan, designed to achieve a minimum of 50 percent reduction of total 

inlet mercury from all Electric Utility Steam Generating Units 

(EUSGUs), specified in Condition IV.E.3, until December 31, 2015. 

Compliance with this O&M plan does not require any mercury emission 

limitations or any commitments to achieve any mercury emission 

reductions. 

3. Mercury Control Strategy O&M Plan 

a. The PM emissions CAM plan outlined in Condition II.C.3.b 

shall be followed to assure proper operation and maintenance of 

the fabric filters for control of mercury emissions from Unit 1 

and Unit 2. 

b. The PM emissions CAM plan outlined in Condition III.C.3.b 

shall be followed to assure proper operation and maintenance of 

the fabric filters for control of mercury emissions from Unit 3 

and Unit 4. 

c. The SO2 emissions monitoring requirements outlined in 

Condition III.D.3 shall be followed to assure proper operation 

and maintenance of the spray dryer absorbers for control of 

mercury emissions from Unit 3 and Unit 4. 

d. The NOx emissions monitoring requirements outlined in 

Condition III.E.3 shall be followed to assure proper operation 

and maintenance of the selective catalytic reduction system for 

control of mercury emissions from Unit 3 and Unit 4. 

4. The Permittee shall be allowed to operate, test, and evaluate the 

performance of the activated carbon injection system (ACI) installed at 

Unit 4. 

5. Monitoring/Recordkeeping/Reporting Requirements 

a. The Permittee shall perform annual mercury stack tests for all 

boiler units during the time period defined in Condition IV.E.2. 

For Unit 3 and Unit 4 testing completed under Condition III.J.2 

satisfies this annual testing requirement. Stack tests shall be 

performed using EPA Method 29 or other EPA-approved 

methods. The results shall be reported as outlet mercury rate in 

lb/MMBtu. 
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b. The Permittee shall conduct mercury and heating value analysis 

at least once per month for each coal type to determine monthly 

inlet mercury in lb/MMBtu. For purposes of this condition, inlet 

mercury means the average concentration of mercury in the coal 

burned at SGS as determined by ASTM methods, EPA approved 

methods or any alternative method approved by the Director. 

Coal sample analysis provided by the coal supplier may be 

utilized for this purpose. 

c. The Permittee shall determine and record for each calendar year 

the facility-wide annual percent reduction of mercury emissions, 

using the inlet and outlet mercury data obtained from Conditions 

IV.E.5.a and b. 

d. The Permittee shall submit annual reports to the Director 

containing the results of Conditions IV.E.5.a through c. The 

report shall be submitted by February 15th and shall contain the 

results for the preceding year. 

6. The Permittee shall submit an application for a significant permit 

revision required by A.A.C. R18-2-734(F) by no later than January 1, 

2014, and shall include the following elements in the application: 

a. The State Mercury Standard and any amendments adopted by 

ADEQ to ensure that the State Mercury Standard is not 

incompatible with a MACT standard promulgated by EPA. 

b. A control strategy for meeting the State Mercury Standard and 

any amendments adopted by ADEQ to ensure that the State 

Mercury Standard is not incompatible with a MACT standard 

promulgated by EPA. 

c. A demonstration that the control strategy is designed to meet the 

State Mercury Standard and any amendments adopted by ADEQ 

to ensure that the State Mercury Standard is not incompatible 

with a MACT standard promulgated by EPA. 

d. A proposal to comply with the State Mercury Standard by 

December 31, 2016, except as provided in A.A.C. R18-2-

734(H), under the following conditions; 

(1) For the purposes of applying the exception established in 

A.A.C. R18-2-734(H), each date specified in that 

provision shall be increased by three calendar years. 

(2) The exception in A.A.C. R18-2-734(G) shall not apply. 
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V. AUXILIARY BOILER (P5) 

A. Applicability 

This Section applies to the Auxiliary Boiler listed in Equipment List, Attachment 

“C”. 

B. Operating Limitations 

1. Fuel Limitations 

a. The Permittee shall burn only No. 2 diesel fuel or bio-diesel in 

the auxiliary boiler. [A.A.C. R18-2-306.A.2] 

b. The Permittee shall not use high sulfur oil (fuel sulfur content 

0.9 percent by weight) as a fuel unless the Permittee 

demonstrates to the satisfaction of the Director that sufficient 

quantities of low sulfur oil are not available for use by the source 

and that it has adequate facilities and contingency plans to insure 

that the SO2 ambient air quality standards set forth in A.A.C. 

R18-2-202 will not be violated. [A.A.C. R18-2-724.G]

2. Monitoring/Recordkeeping/Reporting Requirements [A.A.C.R18-2-306.A.4] 

a. The Permittee shall record the dates and hours of operation of 

the auxiliary boiler. 

b. The Permittee shall submit the dates and hours of operation of 

the auxiliary boiler for the period of each compliance 

certification. 

3. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R-18-724.G. 

C. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity [A.A.C. R18-2-724.J]

The Permittee shall not cause, allow or permit to be emitted into 

the atmosphere from the auxiliary boiler, smoke which exceeds 

15 percent opacity. 

b. Particulate Matter [A.A.C. R18-2-724.C.1]

The Permittee shall not cause, allow or permit the emission of 

PM, caused by the combustion of fuel, from the auxiliary boiler 
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in excess of the amount calculated by the following equation: 

E = 1.02 Q0.769

Where: 

E = the maximum allowable particulate emissions rate in 

pounds-mass per hour. 

Q = the heat input in million Btu per hour. 

2. Monitoring/Recordkeeping/Reporting Requirements 

a. Visible Emissions 

(1) For every 120 hours of continuous operation, a certified 

EPA Reference Method 9 observer shall conduct a 

survey of visible emissions emanating from the stack of 

the auxiliary boiler. If the opacity of the emissions 

observed appears to exceed the standard, the observer 

shall conduct a certified EPA Reference Method 9 

observation. The Permittee shall keep records of the 

survey and any EPA Reference Method 9 observations 

performed. These records shall include the emission 

point observed, location of observer, name of observer, 

date and time of observation, and the results of the 

observation. If the observation shows a Method 9 

opacity reading in excess of 15 percent, the Permittee 

shall initiate appropriate corrective action to reduce the 

opacity below 15 percent. The Permittee shall keep a 

record of the corrective action performed. 

[A.A.C. R18-2-306.A.3.c] 

(2) All opacity readings will be observed in accordance with 

EPA Reference Method 9. The Permittee shall keep a 

record of the opacity readings from above and the 

number of hours fuel oil is burned continuously. 

[A.A.C. R18-2-306.A.3.c] 

(3) The Permittee shall report all six-minute periods in 

which the opacity of any plume or effluent exceeds 15 

percent from the auxiliary boiler. [A.A.C.R18-2-724.J] 

b. Particulate Matter [A.A.C. R18-2-306.A.4]

The Permittee shall keep on record, along with the fuel firing 

rate, the contractual agreement with the liquid fuel vendor 

containing the specifications of the liquid fuel being fired for the 

following parameters: 

(1) The higher heating value, and 
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(2) The ash content 

3. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C. R-18-724.C.1 and J. 

D. Sulfur Dioxide (SO2)

1. Emission Limitations/Standards 

The Permittee shall not cause, allow, or permit the emission of more than 

1.0 pounds of SO2 per million Btu heat input. [A.A.C. R18-2-724.E] 

2. Monitoring/Recordkeeping/Reporting Requirements [A.A.C.R18-2-306.A.4] 

a. The Permittee shall keep records of fuel supplier contractual 

agreement including the following information: 

(1) The name of the oil supplier; 

(2) The sulfur content and heating value of the oil from 

which the shipment came; and 

(3) The method used to determine the sulfur content of the 

oil. 

b. The Permittee shall maintain records of all emissions 

calculations performed for any change in Condition V.D.2.a (2) 

according to the following equation: 

SO2 (lb/MMBtu) =2.0 x [(Weight percent of sulfur/100) x (Density in 

lb/gal)] ÷ [Heating value of fuel in Btu/gal x 1 

MMBtu / 1,000,000 Btu] 

3. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R-18-2-724.E. 

VI. EMERGENCY INTERNAL COMBUSTION ENGINES (ICEs) 

A. Applicability 

This Section applies to emergency diesel generator and diesel fire pumps listed in 

Equipment List, Attachment “C”. 
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B. Operating Limitations 

1. Fuel Limitation [A.A.C. R18-2-306.A.2] 

The Permittee shall burn only diesel fuel or bio-diesel in the ICEs. 

2. Hourly Limitations [A.A.C. R18-2-306.A.2] 

The Permittee shall limit the hours of operation for each ICE to no more 

than 500 hours per year in any rolling 12- month period. 

3. Record Keeping Requirements [A.A.C. R18-2-306.A.3.c] 

The Permittee shall keep records of the rolling 12-month total hours of 

operation of each ICE to demonstrate compliance with the hourly 

limitation in Condition VI.B.2. 

C. Existing Source Requirements 

1. Applicability 

This Section applies to the emergency diesel generator and diesel fire 

pumps marked as ‘No’ under the New Source Performance Standards 

(NSPS) Applicability column in the Equipment List, Attachment “C”. 

 2. Particulate Matter & Opacity 

a. Emission Limitations and Standards [A.A.C.R18-2-719.C.1] 

(1) The Permittee shall not cause, allow or permit the 

emission of particulate matter, caused by combustion of 

fuel in excess of the amounts calculated by the following 

equation: 

E = 1.02Q0.769

Where: 

E = the maximum allowable particulate emissions 

rate in pounds-mass per hour. 

Q = the heat input in million BTU per hour. 

(2) For the purpose of this Section, the heat input shall be 

the aggregate heat content of all fuels whose products of 

combustion pass through a stack or other outlet. The 

total heat input of all operating fuel-burning units on a 

plant or premises shall be used for determining the 

maximum allowable amount of particulate matter which 

may be emitted. [A.A.C. R18-2-719.B] 
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(3) Opacity [A.A.C. R18-2-719.E] 

(a) The Permittee shall not cause, allow or permit to 

be emitted into the atmosphere from any 

stationary rotating machinery, smoke for any 

period greater than 10 consecutive seconds 

which exceeds 40 percent opacity. 

(b) Visible emissions when starting cold equipment 

shall be exempt from this requirement for the 

first 10 minutes. 

b. Monitoring/Recordkeeping/Reporting Requirements

 [A.A.C. R18-2-306.A.3.c] 

(1) The Permittee shall maintain a record of the daily lower 

heating value of the fuel fired in the ICEs and gear 

arrestor engines. This may be accomplished by 

maintaining on record a copy of that part of the contract 

with the vendor that specifies the lower heating value of 

the fuel. 

(2) For every 120 hours of continuous operation of the 

internal combustion engines, a certified EPA Reference 

Method 9 observer shall conduct a survey of visible 

emissions emanating from the stacks of all internal 

combustion engines as described in Attachment “C” of 

this permit. If the opacity of the emissions observed 

appears to exceed the applicable opacity standard, the 

observer shall conduct a certified EPA Reference 

Method 9 observation. The Permittee shall keep records 

of the survey and any EPA Reference Method 9 

observations performed. These records shall include the 

emission point observed, location of observer, name of 

observer, date and time of observation, and the results of 

the observation. 

(3) If the observation results in a Method 9 opacity reading 

in excess of the applicable standard, the Permittee shall 

report this to ADEQ as excess emission and initiate 

appropriate corrective action to reduce the opacity below 

the applicable standard. The Permittee shall keep a 

record of the corrective action performed. 

c. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R18-2-719.B, C.1, and E. 
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3. Sulfur Dioxide (SO2) 

a. Emission Limitations and Standards 

(1) The Permittee shall not cause to emit more than 1.0 

pound of SO2 per million Btu heat input when low sulfur 

oil is fired. [A.A.C. R18-2-719.F]

(2) The Permittee shall not fire high sulfur oil (greater than 

0.9 percent sulfur) in the ICEs. [A.A.C. R18-2-719.H] 

b. Monitoring/Recordkeeping/Reporting Requirements

 [A.A.C.R18-2-306.A.3.c] 

(1) The Permittee shall monitor the sulfur content of the fuel 

being combusted in the ICEs. The Permittee shall 

maintain records of the daily sulfur content and lower 

heating value of the fuel fired in the internal combustion 

engines. This may be accomplished by maintaining on 

record a copy of fuel supplier certifications that specify 

the sulfur content and lower heating value of the fuel. 

[A.A.C. R18-2-306.A.3.c and -719.I] 

(2) The Permittee shall report to the Director any daily 

period during which the sulfur content of the fuel being 

fired in the machine exceeds 0.8 percent. 

[A.A.C. R18-2-719.J and 306.A.3] 

c. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R18-2-719.F, H, I, and J. 

D. New Source Performance Standards (NSPS) Subpart IIII Requirements 

1. Applicability 

a. This Section applies to the emergency ICEs marked as ‘Yes, 

Subpart IIII’ under the NSPS Applicability column in the 

Equipment List, Attachment “C”. 

b. Emergency ICE Definition [40 CFR 60.4219]

Except as provided in Condition VI.D.2.b, an emergency ICE 

shall be limited to emergency situations and required testing and 

maintenance only such as to produce power for critical networks 

or equipment (including power supplied to portions of a facility) 

when electric power from the local utility (or the normal power 

source) is interrupted, or used to pump water in the case of fire 

or flood, etc. 
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2. Operating Requirements 

a. The Permittee shall install a non-resettable hour meter prior to 

startup of the engine.

[40 CFR 60.4209(a), A.A.C. R18-2-306.A.3, and -331.A.3.a] 

b. Operation of the ICE other than emergency operation, 

maintenance and testing, and operation in non-emergency 

situations for more than 50 hours per year, is prohibited. These 

50 hours of operation shall be counted towards the 100 hours per 

year provided for maintenance and testing. [40 CFR 60.4211(f)]

c. There is no time limit on the use of emergency ICE in 

emergency situations. [40 CFR 60.4211(f)] 

d. The Permittee shall operate and maintain the ICE and the control 

device according to the manufacturer’s written instructions. A 

copy of the instructions or procedures shall be kept onsite and 

made available to ADEQ upon request. 

[40 CFR 60.4211(a)(1) and A.A.C. R18-2-306.A.3] 

e. The Permittee shall only change those emission related settings 

that are permitted by the manufacturer. [40 CFR 60.4211(a)(2)] 

f. The Permittee shall meet the applicable requirements of 40 CFR 

Part 89, 94 and 1068. [40 CFR 60.4211(a)(3)] 

g. The Permittee may operate the stationary ICE for the purpose of 

maintenance checks and readiness testing, provided that the tests 

are recommended by Federal, State, or local government, the 

manufacturer, the vendor, or the insurance company associated 

with the engine. Maintenance checks and readiness testing of 

such units is limited to 100 hours per year. The Permittee may 

petition the Administrator and the Director for approval of 

additional hours to be used for maintenance checks and readiness 

testing, but a petition is not required if the Permittee maintains 

records indicating that Federal, State, or local standards require 

maintenance and testing of emergency ICE beyond 100 hours 

per year. [40 CFR 60.4211(f)] 

3. Fuel Requirements [40 CFR 60.4207(b)] 

The Permittee operating a stationary ICE shall use diesel fuel or biodiesel that meets the requirements of non road diesel fuel listed in 40 

CFR 80.510(b) and listed below: 

a. Sulfur content: 15 ppm maximum; and 

b A minimum cetane index of 40 or a maximum aromatic content 

of 35 volume percent. 
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4. Emission Limitations and Standards [40 CFR 60.4205 (c) and Table 4] 

a. Non-methane hydrocarbons (NMHC) and Nitrogen Oxides 

(NOx) 

The Permittee shall limit the combined emissions of NMHC and 

NOx from the ICE to 10.5 g/Kw-hr. 

b. Carbon Monoxide (CO) 

The Permittee shall limit the emissions of CO from the ICE to 

3.5 g/Kw-hr. 

c. Particulate Matter (PM) 

The Permittee shall limit the emissions of PM from the ICE to 

0.54 g/Kw-hr. 

5. Recordkeeping & Reporting Requirements 

a. The Permittee shall maintain a copy of engine certification or 

other documentation demonstrating that the engine complies 

with the applicable standards in this permit, and shall make the 

documentation available to ADEQ upon request. 

[40 CFR 60.4211(c)] 

b. The Permittee shall record the time of operation of the engine 

and the reason the engine was in operation during that time. 

[40 CFR 60.4214(b)] 

c. The Permittee shall keep records of fuel supplier specifications. 

The specifications shall contain name of the supplier, sulfur 

content, and cetane index or aromatic content in the fuel. These 

records shall be made available to ADEQ upon request. 

[A.A.C.R18-2-306.A.3.c] 

6. Permit Shield [A.A.C.R18-2-325] 

Compliance with the conditions of this Section shall be deemed 

compliance with 40 CFR 60. 4205(c), (e), & (f), 4207(b), 4209(a), 

4211(a)(1), (2) & (3), (c), & (f), 4214(b), and 4219. 

E. National Emission Standards for Hazardous Air Pollutants (NESHAP) 

Subpart ZZZZ Requirements 

1. Applicability 

a. This Section is applicable to emergency ICEs marked as ‘Yes, 

Subpart ZZZZ’ in NESHAP applicability column in Equipment 

List, Attachment “C”. 

b. Emergency stationary ICE means any stationary internal 

combustion engine whose operation is limited to emergency 
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situations and required testing and maintenance. [40 CFR 63.6675]

c. The Permittee shall comply with the terms of this Section no 

later than May 3, 2013. [40 CFR 63.6595(a)(1)]

2. Operating Requirements [40 CFR 63.6605] 

a. The Permittee shall operate and maintain the emergency fire 

pump engine 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 the Permittee 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 and the Director 

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)] 

b. The Permittee shall minimize the engine's time spent at idle 

during startup and minimize the engine's startup time to a period 

needed for appropriate and safe loading of the engine, not to 

exceed 30 minutes, after which time the emission standards 

applicable to all times other than startup in Table 2c to 40 CFR 

Part 63 subpart ZZZZ apply. [40 CFR 63.6625 (h)]

c. The Permittee shall operate each ICE according to the 

requirements in following paragraphs VI.E.2.c.i and VI.E.2.c.ii 

of this section. If the engine is not operated according to the 

requirements in paragraphs VI.E.2.c.i and VI.E.2.c.ii of this 

Condition, the engine will not be considered an emergency 

engine and shall meet all requirements for non-emergency 

engines. [40 CFR 63.6640 (f)]

(1) The Permittee may operate the emergency engines for 

the purpose of maintenance checks and readiness testing, 

provided that the tests are recommended by Federal, 

State, or local government, the manufacturer, the vendor, 

or the insurance company associated with the engine. 

Maintenance checks and readiness testing of the engine 

is limited to no more than 100 hours per year. The 

Permittee may petition the Administrator and the 

Director for approval of additional hours to be used for 

maintenance checks and readiness testing, but a petition 

is not required if the Permittee maintains records 

indicating that the Federal, State, or local standards 

require maintenance and testing beyond 100 hours per 

year. Copies of records shall be made available to 

ADEQ upon request.
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(2) The Permittee may operate the emergency engines for up 

to 50 hours per year in non-emergency situations, but 

those 50 hours are counted towards the 100 hours per 

year provided for maintenance and testing. The 50 hours 

per year for non-emergency situations cannot be used for 

peak shaving or to generate income for a facility to 

supply power to an electric grid or otherwise supply 

power as part of a financial arrangement with another 

entity; except that the Permittee may operate the 

emergency engine for a maximum of 15 hours per year 

as part of a demand response program if the regional 

transmission organization or equivalent balancing 

authority and transmission operator has determined there 

are emergency conditions that could lead to a potential 

electrical blackout, such as unusually low frequency, 

equipment overload, capacity or energy deficiency, or 

unacceptable voltage level. The engine may not be 

operated for more than 30 minutes prior to the time 

when the emergency condition is expected to occur, and 

the engine operation must be terminated immediately 

after the facility is notified that the emergency condition 

is no longer imminent. The 15 hours per year of demand 

response operation are counted as part of the 50 hours of 

operation per year provided for non-emergency 

situations. The supply of emergency power to another 

entity or entities pursuant to financial arrangement is not 

limited by this paragraph, as long as the power provided 

by the financial arrangement is limited to emergency 

power. 

e. The Permittee shall install a non-resettable hour meter on the 

emergency fire pump engine. [40 CFR 63.6625(f) and A.A.C. R18-2-331.A.3.a] 

f. The Permittee shall change oil and filter every 500 hours of 

operation or annually, whichever comes first. If the Permittee 

prefers to extend the oil change requirement, an oil analysis 

program as described in 40 CFR 63.6625(i) shall be completed. 

[40 CFR 63.6603(a), Table 2d of Subpart ZZZZ, and 63.6625(i)] 

g. The Permittee shall inspect air cleaner every 1,000 hours of 

operation or annually, whichever comes first; 

[40 CFR 63.6603(a); Table 2d of Subpart ZZZZ]

h. The Permittee shall inspect all hoses and belts every 500 hours 

of operation or annually, whichever comes first, and replace as 

necessary. [40 CFR 63.6603(a); Table 2d of Subpart ZZZZ] 

i. The Permittee shall operate and maintain the emergency fire 

pump engine according to the manufacturer's emission-related 

written instructions or develop a maintenance plan which must 
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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)] 

3. Recordkeeping Requirements 

a. The Permittee shall keep records of the hours of operation of 

each emergency engine that is recorded through the nonresettable hour meter. Records shall include the date, start and 

stop times, hours spent for emergency operation, including what 

classified the operation as emergency and how many hours are 

spent for non-emergency operation. [40 CFR 63.6655(f)] 

b. If the Permittee elects to implement the oil analysis program 

described in 40 CFR 63.6625(i), the Permittee shall keep records 

of the parameters that are analyzed and the results of the oil 

analysis and the oil changes for the engine. [40 CFR 63.6625(i)] 

c. The Permittee shall keep records of the maintenance conducted 

on the emergency fire pump that demonstrates operation and 

maintenance in accordance with the maintenance plan. 

[40 CFR 63.6655(e)] 

d. The Permittee shall document the hours spent for emergency 

operation, including what classified the operation as emergency 

and how many hours are spent for non-emergency operation. If 

the engines are used for demand response operation, the 

Permittee shall keep records of the notification of the emergency 

situation, and the time the engine was operated as part of demand 

response. [40 CFR 63.6655(f)] 

4. Compliance Requirements [40 CFR 63.6590(c)]

The Permittee, for the emergency ICE subject to NSPS Subpart IIII shall 

comply with the requirements of NESHAP ZZZZ by meeting 

requirements of NSPS Subpart IIII. 

5. Permit Shield [A.A.C. R18-2-325] 

Compliance with the conditions of this Section shall be deemed 

compliance with 40 CFR Part 63.6590 (c), 6595 (a)(1), 6603(a), 6605(b), 

6625(e) & (f), 6640(f), 6655(e) & (f), Table 2d of 40 CFR subpart ZZZZ, 

and 6675. 

VII. COOLING TOWERS 

A. Applicability 

This Section applies to Cooling Towers described in Condition #s I.D.3 and 4, 

and Equipment List, Attachment “C”. 
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B. Operating Limitations 

1. Gaseous or Odorous Materials 

a. The Permittee shall not emit gaseous or odorous materials from 

equipment, operations or premises in such quantities or 

concentrations as to cause air pollution. [A.A.C. R18-2-730.D]

b. Where a stack, vent, or other outlet is at such a level that fumes, 

gas mist, odor, smoke, vapor or any combination thereof 

constituting air pollution is discharged to adjoining property, the 

Director may require the installation of abatement equipment or 

the alteration of such stack, vent, or other outlet by the Permittee 

thereof to a degree that will adequately dilute, reduce, or 

eliminate the discharge of air pollution to adjoining property. 

[A.A.C. R18-2-730.G] 

2. Flow Rate Limitation [A.A.C. R18-2-306.A.2 and -406.A.4] 

a. The Permittee shall not cause, allow or permit the total 

circulating water flow rate in CT 1 or CT 2 to exceed 176,000 

gallons per minute, total for the thirteen cells in each tower. 

b. The Permittee shall not cause, allow or permit the total 

circulating water flow rate in CT 3 or CT 4 to exceed 200,000 

gallons per minute. 

3. Permit Shield [A.A.C.R18-2-325]

Compliance with the conditions of this Section shall be deemed 

compliance with A.A.C.R-18-730.D and G. 

C. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Particulate Matter 

(1) The Permittee shall not discharge PM into the 

atmosphere in any one hour from any CT in total 

quantities in excess of the amounts calculated by the 

following equation: [A.A.C. R18-2-730.A.1 and B] 

E = 55.0 P0.11 - 40 

Where: 

E = the maximum allowable particulate emissions rate 

in pounds-mass per hour. 

P = the process weight rate in tons-mass per hour. 
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(2) The total process weight from all similar units 

employing a similar type process shall be used in 

determining the maximum allowable emission of 

particulate matter. 

(3) The Permittee shall not discharge into the atmosphere 

from CT 1 or CT 2 any gases which contain PM in 

excess of 108.4 lbs per hour, total for the thirteen cells in 

each tower. [A.A.C. R18-2-406.A.4] 

(4) The Permittee shall not discharge into the atmosphere 

from CT 3 or CT 4 any gases which contain PM in 

excess of 12.32 lbs per hour, total for each tower. 

[A.A.C. R18-2-406.A.4] 

b. Opacity 

(1) The Permittee shall not cause, allow or permit to be 

emitted into the atmosphere any visible emissions in 

excess of 20 percent opacity measured in accordance 

with EPA Reference Method 9. [A.A.C.R18-2-702.B.1]

(2) If the presence of uncombined water is the only reason 

for an exceedance of any visible emissions requirement, 

the exceedance shall not constitute a violation of the 

opacity limit specified in Condition VII.C.1.b. (1). [A.A.C. R18-2-702.C]

2. Air Pollution Control Requirements 

[Material Permit Conditions are defined by underline and italics] 

a. The Permittee shall not cause, allow or permit the operation of 

CTs without properly maintaining the drift eliminators.

[A.A.C. R18-2-306.A.2 and -331.A.3.e] 

b. The drift eliminators for CT 1 and CT 2 shall be designed for a 

total liquid drift not to exceed 0.005 percent of the circulating 

water flow rate. [A.A.C. R18-2-306.A.2, -331.A.3.e, and -406.A.4] 

c. The drift eliminators for CT 3 and CT 4 shall be designed for a 

total liquid drift not to exceed 0.0005 percent of the circulating 

water flow rate. [A.A.C. R18-2-306.A.2, -331.A.3.e, and -406.A.4] 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Particulate Matter [A.A.C. R18-2-306.A.3.c]

The Permittee shall comply with the following requirements: 

(1) The Permittee shall maintain readily available records of 

the design and vendor-guaranteed maximum total liquid 
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drift of each CT. 

(2) The Permittee shall maintain readily available records of 

the design maximum pumping capacity of each of the 

water pumps serving the CTs. 

(3) The Permittee shall measure and record twice per month 

the Total Dissolved Solids (TDS) of the circulating 

water used in each CT. Solids measurement shall be 

performed using EPA Method 160.3 (in Methods for the 

Chemical Analysis of Water and Wastes; EPA-600/4-79-

020; U.S. EPA, Environmental Monitoring and Systems 

Laboratory, Cincinnati, Ohio) or equivalent method as 

approved by the Director. 

(4) The Permittee shall calculate twice per month the 

particulate matter emission rate from each CT. Each CT 

emission rate calculation shall be calculated using the 

vendor-guaranteed maximum total liquid drift for the CT 

and drift eliminators, the design maximum pumping 

capacity for the CT, and the measured TDS of the 

circulating water in the CT. A calculated particulate 

matter emission rate exceeding the limitation in 

Conditions VII.C.1.a (3) and (4) shall constitute a period 

of excess emissions.

b. Opacity [A.A.C.R18-2-306.A.3.c] 

(1) A certified Method 9 observer shall conduct a weekly 

visual survey of visible emissions from the cooling 

towers when it is in operation. The Permittee shall 

record the name of the observer, the date the observation 

was made, and the results of the observation. 

(2) If the observer sees a plume from an emission point that 

on an instantaneous basis appears to exceed the opacity 

standard in Condition VII.C.1.b, the observer shall, if 

possible, take a six-minute Method 9 observation of the 

plume. 

(3) If the six-minute opacity of the plume exceeds the 

opacity standard in Condition VII.C.1.b the Permittee 

shall do the following: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the opacity standard in 

condition VII.C.1.b; and 

(b) Report it as an excess emission in accordance 

with Condition XII.A of Attachment “A” of this 
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permit. 

(4) If the six-minute opacity of the plume is less than the 

opacity standard in Condition VII.C.1.b, the observer 

shall make a record of the following: 

(a) Date and time of the test; and 

(b) The results of the Method 9 observation. 

4. Permit Shield [A.A.C.R18-2-325]

Compliance with the conditions of this Section shall be deemed 

compliance with A.A.C.R-18-2-702.B.1, -730.A.1 and B. 

VIII. COAL PREPARATION PLANT 

A. Applicability 

This Section applies to the Coal Preparation Plants described in Equipment List, 

Attachment “C”. 

B. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity [Material Permit Conditions are defined by underline and italics] 

(1) The Permittee shall not cause to be discharged into the 

atmosphere from any coal processing and conveying 

equipment, coal storage system (except for open storage 

piles), or coal transfer and loading system processing 

coal, gases which exhibit 20 percent opacity or greater.

[40 CFR 60.252(c) and A.A.C. R18-2-331.A.3.f] 

(2) The Permittee shall not cause to be discharged into the 

atmosphere from any coal preparation plant fabric filter 

baghouse any gases which exhibit 20 percent opacity or 

greater. This emission standard shall not apply during 

periods of startup, shutdown, or malfunction (Condition 

#s I.D.8, 12, and 14). 

[40 CFR 60.252(c) and A.A.C. R18-2-331.A.3.f] 

(3) The Permittee shall not cause to be discharged into the 

atmosphere from any coal preparation plant fabric filter 

baghouse installed as part of the Unit 3 and Unit 4 

modernization any gases which exhibit 10 percent 

opacity or greater. This emission standard shall not 

apply during periods of startup, shutdown, or 

malfunction (Condition #s I.D.8, 12, and 14).

[40 CFR 60.252(c), A.A.C. R18-2-331.A.3.f, and -406.A.4] 
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Tucson Electric Power-SGS 

(4) The Permittee shall not cause to be discharged into the 

atmosphere from any coal storage pile emissions which 

exhibit 40 percent opacity or greater.

[A.A.C. R18-2-331.A.3.f, -406.A.4, and-614] 

b. Particulate Matter 

The Permittee shall not cause to be discharged into the 

atmosphere from any coal preparation plant fabric filter 

baghouse installed as part of the Unit 3 and Unit 4 

modernization, any gases containing PM in excess of 0.01 grains 

per dry standard cubic foot. [A.A.C. R18-2-406.A.4] 

2. Air Pollution Control Requirements 

[Material Permit Conditions are defined by underline and italics] 

a. At all times when the system is in operation, including periods of 

startup, shutdown, and malfunction (as defined in Condition #s 

I.D.8, 12, and 14), the Permittee shall, to the extent practicable,

maintain and operate the baghouses to capture PM emissions 

associated with coal preparation and mixing in a manner 

consistent with good air pollution control practices.

[40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e] 

b. The Permittee shall operate and maintain at all times a covered 

conveyor belt transfer system. [A.A.C. R18-2-306.A.2 and -331.A.3.e] 

c. The Permittee shall utilize water spray with surfactant as 

necessary to control PM emissions at the active and emergency 

coal storage pile(s). [A.A.C. R18-2-306.A.2 and -331.A.3.e]

d. The Permittee shall utilize enclosures and water spray with 

surfactant as necessary to control PM emissions at the rail 

unloading area and the emergency reclaim hopper.

[A.A.C. R18-2-306.A.2 and -331.A.3.e] 

e. The Permittee shall utilize enclosures and fabric filter baghouses 

to control PM emissions at all coal handling locations other than 

the active coal storage pile(s) and the locations listed in 

Conditions VIII.B.2.c & d. The locations controlled with 

enclosures and fabric filter baghouses shall include the 

following: [A.A.C. R18-2-306.A.2 and -331.A.3.e]

(1) Transfer towers; 

(2) Crusher towers; 

(3) Discharge hoppers; and 

(4) Coal storage silos. 
Permit #53418 99 of 131 August 15, 2012 

Tucson Electric Power-SGS 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Opacity Monitoring [A.A.C. R18-2-306.A.3.c] 

(1) A certified Method 9 observer shall conduct a weekly 

visual survey of visible emissions from the coal 

preparation plant when in operation. This weekly survey 

shall include observation of all exposed transfer points, 

enclosed transfer points, the coal storage system, the 

coal storage pile and the baghouses in the coal handling 

system. The Permittee shall keep a record of the name 

of the observer, the date on which the observation was 

made, and the results of the observation. 

(2) If the observer sees a plume from an emission point that 

on an instantaneous basis appears to exceed the 

applicable opacity standard in Condition VIII.B.1.a, the 

observer shall if possible take a six-minute Method 9 

observation of the plume. 

(3) If the six-minute opacity of the plume exceeds the 

applicable opacity standard in Condition VIII.B.1.a, the 

Permittee shall do the following: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the applicable opacity 

standard in Condition VIII.B.1.a; and 

(b) Report it as an excess emission in accordance 

with Section XII.A of Attachment A of this 

permit. 

(4) If the six-minute opacity of the plume is less than the 

applicable opacity standard in Condition VIII.B.1.a, the 

observer shall make a record of the following: 

(a) Date and time of the test; and 

(b) The results of the Method 9 observation. 

4. Testing for PM 

For the baghouses, if an opacity exceedance is detected during the course 

of the weekly visible emissions survey and the Permittee is unable to 

identify adjustments or repairs necessary to address the opacity violation 

within 72 hours, the Permittee shall conduct a performance test for those 

baghouses within 180 days to show compliance with the PM limit 

identified in Condition VIII.B.1.b. [A.A.C. R18-2-306.A.3.c and -406.A.4] 
Permit #53418 100 of 131 August 15, 2012 

Tucson Electric Power-SGS 

5. Permit Shield [A.A.C.R18-2-325]

Compliance with the conditions of this Section shall be compliance with 

40 CFR 60.252(c). 

IX. LIME HANDLING – UNIT 1 AND UNIT 2 

A. Applicability 

This Section applies to Lime Handling Unit 1 and Unit 2 as described in 

Attachment “C”. 

B. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity [A.A.C. R18-2-702.B.1] 

The Permittee shall not cause, allow or permit to be emitted into 

the atmosphere from any lime handling operation any visible 

emissions in excess of 20 percent opacity measured in 

accordance with EPA Reference Method 9. 

b. Particulate Matter [A.A.C. R18-2-730.A.1 and B]

The Permittee shall not cause, allow or permit the discharge of 

PM into the atmosphere in any one hour from any lime handling 

operation in total quantities in excess of the amounts calculated 

by the following equations: 

(1) For process sources having a process weight rate of 

60,000 pounds per hour (30 tons per hour) or less, the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 4.10 P0.67 

Where: 

E = the maximum allowable particulate emissions rate 

in pounds-mass per hour. 

P = the process weight rate in tons-mass per hour. 

 (2) For process sources having a process weight rate greater 

than 60,000 pounds per hour (30 tons per hour), the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 55.0 P0.11 - 40 
Permit #53418 101 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Where: 

E = the maximum allowable particulate emissions rate 

in pounds-mass per hour. 

P = the process weight rate in tons-mass per hour. 

(3) The total process weight from all similar units 

employing a similar type process shall be used in 

determining the maximum allowable emission of PM. 

2. Air Pollution Control Requirements 

At all times when the system is in operation, the Permittee shall maintain 

and operate the enclosure system and baghouses used to capture PM

emissions associated with lime handling system in a manner consistent 

with good air pollution control practices.

[A.A.C. R18-2-306.A.2 and R18-2-331.A.3.e] 

[Material Permit Conditions are defined by underline and italics] 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Opacity [A.A.C. R18-2-306.A.3.c] 

(1) A certified Method 9 observer shall conduct a weekly 

visual survey of visible emissions from the lime 

handling system when in operation. This weekly 

observation shall include observation of all exposed 

transfer points and each baghouse exhaust. The 

Permittee shall keep a record of the name of the 

observer, the date on which the observation was made, 

and the results of the observation. 

(2) If the observer sees a plume from an emission point that 

on an instantaneous basis appears to exceed the 

applicable opacity standard in Condition IX.B.1.a, the 

observer shall, if possible, take a six-minute Method 9 

observation of the plume. 

(3) If the six-minute opacity of the plume exceeds the 

applicable opacity standard in Condition IX.B.1.a, the 

Permittee shall: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the opacity standard in 

Condition IX.B.1.a; and 

(b) Report it as an excess emission in accordance 

with Condition XII.A of Attachment “A” of this 

permit. 
Permit #53418 102 of 131 August 15, 2012 

Tucson Electric Power-SGS 

(4) If the six-minute opacity of the plume is less than the 

applicable opacity standard in Condition IX.B.1.a, the 

observer shall make a record of the following: 

(a) Date and time of the test; and 

(b) The results of the Method 9 observation. 

b. Particulate Matter [A.A.C. R18-2-306.A.3.c]

(1) The Permittee shall maintain and operate the baghouses 

in accordance with good operating practices. These 

specifications shall be on file and be readily available for 

inspection by the Director. 

(2) The Permittee shall maintain records of emissions 

related maintenance performed on the baghouses. 

4. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R-18-2-702.B.1, -730.A.1, and B. 

X. LIME HANDLING - UNIT 3 AND UNIT 4 

A. Applicability 

This Section applies to Lime Handling– Unit 3 and Unit 4 as described in 

Equipment List, Attachment “C”. 

B. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity [Material Permit Conditions are defined by underline and italics] 

(1) The Permittee shall not cause to be discharged into the 

atmosphere from any lime handling operation any 

visible emissions in excess of 20 percent opacity 

measured in accordance with EPA Reference Method 9. [A.A.C. R18-2-331.A.3.f, -406.A.4, and -702.B.1] 

(2) The Permittee shall not cause to be discharged into the 

atmosphere from any lime handling system fabric filter 

baghouse any visible emissions in excess of 10 percent 

opacity measured in accordance with EPA Reference 

Method 9. This emission standard shall not apply 

during periods of startup, shutdown, or malfunction (as 

defined in Condition #s I.D.8, 12. and 14).

[A.A.C. R18-2-331.A.3.f, -406.A.4, and -702.B.1] 
Permit #53418 103 of 131 August 15, 2012 

Tucson Electric Power-SGS 

b. Particulate Matter 

(1) The Permittee shall not cause to be discharged into the 

atmosphere from any lime handling system fabric filter 

baghouse any gases containing PM in excess of 0.01 

grains per dry standard cubic foot. [A.A.C. R18-2-406.A.4] 

(2) The Permittee shall not cause, allow or permit the 

discharge of PM into the atmosphere in any one hour 

from any lime handling operation in total quantities in 

excess of the amounts calculated by the following 

equations: [A.A.C. R18-2-730.A.1 and B]

(a) For process sources having a process weight rate 

of 60,000 pounds per hour (30 tons per hour) or 

less, the maximum allowable emissions shall be 

determined by the following equation: 

E = 4.10 P0.67 

Where: 

E = the maximum allowable particulate 

emissions rate in pounds-mass per hour. 

P = the process weight rate in tons-mass per 

hour. 

(b) For process sources having a process weight rate 

greater than 60,000 pounds per hour (30 tons per 

hour), the maximum allowable emissions shall 

be determined by the following equation: 

E = 55.0 P0.11- 40 

Where: 

E =the maximum allowable particulate 

emissions rate in pounds-mass per hour. 

P = the process weight rate in tons-mass per 

hour. 

(c) The total process weight from all similar units 

employing a similar type process shall be used 

in determining the maximum allowable emission 

of particulate matter. 
Permit #53418 104 of 131 August 15, 2012 

Tucson Electric Power-SGS 

2. Air Pollution Control Requirements 

[Material Permit Conditions are defined by underline and italics] 

a. The Permittee shall utilize enclosures and fabric filter baghouses 

to control PM emissions at all lime handling locations.

[A.A.C. R18-2-331.A.3.e and -406.A.4] 

b. At all times when the lime handling system is in operation, 

including periods of startup, shutdown, and malfunction (as 

defined in Condition #s I.D.8, 12, and 14), the Permittee shall

maintain and operate the associated enclosures and fabric filter 

baghouses in a manner consistent with good air pollution 

control practices. [A.A.C. R18-2-331.A.3.e and -406.A.4] 

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Opacity [A.A.C.R18-2-306.A.3.c]

(1) A certified Method 9 observer shall conduct a weekly 

visual survey of visible emissions from the lime 

handling system when in operation. This weekly survey 

shall include observation of all exposed transfer points 

and fabric filter baghouses in the lime handling system. 

The Permittee shall keep a record of the name of the 

observer, the date on which the observation was made, 

and the results of the observation. 

(2) If the observer sees a plume from a lime handling system 

fabric filter baghouse that on an instantaneous basis 

appears to exceed applicable opacity standard, the 

observer shall if possible take a six-minute Method 9 

observation of the plume. 

(3) If the six-minute opacity of the plume from the lime 

handling system baghouse exceeds applicable opacity 

standard, the Permittee shall: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below 10 percent; and 

(b) Report it as an excess emission in accordance 

with Section XII.A of Attachment “A” of this 

permit. 

(4) If the six-minute opacity of the plume from the lime 

handling system baghouse is less than applicable opacity 

standard, the observer shall make a record of the: 

(a) Date and time of the test; and 
Permit #53418 105 of 131 August 15, 2012 

Tucson Electric Power-SGS 

(b) The results of the Method 9 observation. 

(5) If the observer sees a plume from a lime handling system 

emission point other than a fabric filter baghouse that on 

an instantaneous basis appears to exceed the applicable 

opacity standard in Condition X.B.1.a(1), the observer 

shall if possible take a six-minute Method 9 observation 

of the plume. 

(6) If the six-minute opacity of the plume from the lime 

handling system emission point exceeds the applicable 

opacity standard in Condition X.B.1.a (1), the Permittee 

shall: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the opacity standard in 

Condition X.B.1.a (1); and 

(b) Report it as an excess emission in accordance 

with Section XII.A of Attachment “A” of this 

permit. 

(7) If the six-minute opacity of the plume from the lime 

handling system emission point is less than the 

applicable opacity standard in Condition X.B.1.a(1), the 

observer shall make a record of the: 

(a) Date and time of the test; and 

(b) The results of the Method 9 observation. 

b. Particulate Matter [A.A.C.R18-2-306.A.3.c] 

The Permittee shall maintain records of emissions related 

maintenance performed on the lime handling system fabric filter 

baghouses. 

4. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R-18-2-702.B.1, -730.A.1, and B. 

XI. FLY ASH HANDLING - UNIT 1 AND UNIT 2 

A. Applicability 

This Section applies to Fly Ash Handling-Unit 1 and Unit 2 as described in 

Equipment List, Attachment “C”. 
Permit #53418 106 of 131 August 15, 2012 

Tucson Electric Power-SGS 

B. Particulate Matter (PM/PM10) and Opacity 

1. Emission Limitations/Standards 

a. Opacity 

The Permittee shall not cause, allow or permit to be emitted any 

emissions into the atmosphere from the fly ash handling 

operation in excess of 20 percent opacity measured in 

accordance with EPA Reference Method 9. [A.A.C. R18-2-702.B.1] 

b. Particulate Matter [A.A.C. R18-2-730.A.1 and B]

The Permittee shall not cause, allow or permit the discharge of 

PM into the atmosphere in any one hour from any fly ash 

handling operation in total quantities in excess of the amounts 

calculated by the following equations: 

(1) For process sources having a process weight rate of 

60,000 pounds per hour (30 tons per hour) or less, the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 4.10 P 0.67 

Where: 

E = the maximum allowable particulate emissions rate 

in pounds-mass per hour. 

P = the process weight rate in tons-mass per hour. 

 

(2) For process sources having a process weight rate greater 

than 60,000 pounds per hour (30 tons per hour), the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 55.0 P0.11 - 40 

Where E and P are as defined above. 

 (3) The total process weight from all similar units 

employing a similar type process shall be used in 

determining the maximum allowable emission of 

particulate matter. 

2. Air Pollution Control Requirements 

[Material Permit Conditions are defined by underline and italics] 

a. Fly ash shall be collected from the baghouses hoppers, and 

transported to the ash handling system. [A.A.C. R18-2-331.A.3.e and -306.A.2] 
Permit #53418 107 of 131 August 15, 2012 

Tucson Electric Power-SGS 

b. The emissions from dry fly ash unloading shall be ducted 

through a Dust Filter Module. This module shall be maintained 

and operated in accordance with manufacturer’s specifications. 

These specifications shall be on file and shall be readily 

available for inspection by the Department. 

[A.A.C. R18-2-331.A.3.e and -306.A.2] 

c. The emission from the vent of the fly ash storage silos shall be 

ducted to the flue gas system before entering the baghouses. 

[A.A.C. R18-2-331.A.3.e and -306.A.2] 

d. The Permittee shall process transport, load/unload, store, and 

dispose of the Irvington Generating Station (IGS) fly ash in 

compliance with the following: 

(1) The Permittee shall operate and maintain valves and 

piping at Units 1 and 2 fly ash storage silos necessary to 

provide for a sealed transfer of the IGS fly ash to the 

silos. [A.A.C. R18-2-331.A.3.e and -306.A.2] 

(2) Upon receiving the IGS fly ash at the SGS facility and 

thereafter, the Permittee shall not cause, permit, or 

allow the ash haul road to be used by vehicular or nonvehicular traffic without the use of effective oil and chip 

surface with appropriate load-bearing base as required 

to control dust emissions from the ash haul road.

[A.A.C. R18-2-331.A.3.e and -306.A.2] 

(3) Upon receiving the IGS fly ash at the SGS facility and 

thereafter, the Permittee shall not cause, permit, or 

allow the ash haul road to be used by vehicular or nonvehicular traffic unless the ash haul road has been 

watered within the most recent 24 hours. This 

requirement does not apply in the event that the ash haul 

road has received measurable precipitation within the 

most recent 24 hours. [A.A.C. R18-2-331.A.3.e and -306.A.2]

3. Monitoring/Recordkeeping/Reporting Requirements 

a. Opacity [A.A.C. R18-2-306.A.3.c]

(1) A certified Method 9 observer shall conduct a weekly 

visual survey of visible emissions from the fly ash 

handling system when in operation. This weekly 

observation shall include observation of all exposed 

transfer points. The Permittee shall keep a record of the 

name of the observer, the date on which the observation 

was made, and the results of the observation. 

(2) If the observer sees a plume from an emission point that 

on an instantaneous basis appears to exceed the 
Permit #53418 108 of 131 August 15, 2012 

Tucson Electric Power-SGS 

applicable opacity standard in Condition XI.B.1.a, the 

observer shall if possible take a six-minute Method 9 

observation of the plume. 

(3) If the six-minute opacity of the plume exceeds the 

applicable opacity standard in Condition XI.B.1.a, the 

Permittee shall do the following: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the opacity standard in 

Condition XI.B.1.a; and 

(b) Report it as an excess emission in accordance 

with Condition XII.A of Attachment “A” of this 

permit. 

(4) If the six-minute opacity of the plume is less than the 

applicable opacity standard in Condition XI.B.1.a, the 

observer shall make a record of the following: 

(a) Date and time of the test; and 

(b) The results of the Method 9 observation. 

b. Dust Filter Module [A.A.C.R18-2-306.A.3.c]

The Permittee shall maintain records of emissions related 

maintenance performed on the Dust Filter Module. 

4. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed 

compliance with A.A.C.R-18-2-702.B.1, -730.A.1, and B. 

XII. FLY ASH HANDLING - UNIT 3 AND UNIT 4 

A. Applicability 

This Section applies to Fly Ash Handling – Unit 3 and Unit 4 as described in 

Equipment List, Attachment “C”. 

B. Emission Limits and Standards 

1. Opacity [Material Permit Conditions are defined by underline and italics] 

a. The Permittee shall not cause to be discharged into the 

atmosphere from any fly ash handling operation any visible 

emissions in excess of 20 percent opacity measured in 

accordance with EPA Reference Method 9. [A.A.C. R18-2-331.A.3.f, -406.A.4, and -702.B.1] 
Permit #53418 109 of 131 August 15, 2012 

Tucson Electric Power-SGS 

b. The Permittee shall not cause to be discharged into the 

atmosphere from any fly ash handling system fabric filter 

baghouse any visible emissions in excess of 10 percent opacity 

measured in accordance with EPA Reference Method 9. This 

emission standard shall not apply during periods of startup, 

shutdown, or malfunction (Condition #s I.D.8, 12, and 14)

[A.A.C. R18-2-331.A.3.f and -406.A.4] 

2. Particulate Matter 

a. The Permittee shall not cause to be discharged into the 

atmosphere from any fly ash handling system fabric filter 

baghouse any gases containing PM in excess of 0.01 grains per 

dry standard cubic foot. [A.A.C. R18-2-406.A.4] 

b. The Permittee shall not cause, allow or permit the discharge of 

PM into the atmosphere in any one hour from any fly ash 

handling operation in total quantities in excess of the amounts 

calculated by the following equations: [A.A.C. R18-2-730.A.1 and B] 

(1) For process sources having a process weight rate of 

60,000 pounds per hour (30 tons per hour) or less, the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 4.10 P0.67 

Where: 

E = the maximum allowable particulate emissions 

rate in pounds-mass per hour. 

P = the process weight rate in tons-mass per hour. 

The total process weight from all similar units 

employing a similar type process shall be used 

in determining the maximum allowable emission 

of particulate matter. 

(2) For process sources having a process weight rate greater 

than 60,000 pounds per hour (30 tons per hour), the 

maximum allowable emissions shall be determined by 

the following equation: 

E = 55.0 P0.11 - 40 

Where E and P are as defined above. 

 (3) The total process weight from all similar units 

employing a similar type process shall be used in 

determining the maximum allowable emission of 

particulate matter. 
Permit #53418 110 of 131 August 15, 2012 

Tucson Electric Power-SGS 

C. Air Pollution Control Equipment 

[Material Permit Conditions are defined by underline and italics] 

1. The Permittee shall collect fly ash from the Unit 3 and Unit 4 fabric filter 

baghouse hoppers, and any other hoppers that may be installed for fly 

ash collection, and shall transport the fly ash to the fly ash handling 

system. [A.A.C. R18-2-331.A.3.e and -406.A.4] 

2. The Permittee shall utilize enclosures and fabric filter baghouses to 

control particulate matter emissions at all Unit 3 and Unit 4 fly ash 

handling locations other than the fly ash silo truck loading and the ash 

dump. [A.A.C. R18-2-331.A.3.e and -406.A.4] 

3. At all times when the fly ash handling system is in operation, including 

periods of startup, shutdown, and malfunction (as defined in Condition 

I.D.8, 12, and 14), the Permittee shall maintain and operate the 

enclosure systems and the fly ash handling system baghouses in a 

manner consistent with good air pollution control practices. [A.A.C. R18-2-331.A.3.e and -406.A.4] 

D. Monitoring/Recordkeeping/Reporting Requirements 

1. Opacity [A.A.C.R18-2-306.A.3.c] 

a. A certified Method 9 observer shall conduct a weekly visual 

survey of visible emissions from the fly ash handling system 

when it is in operation. This weekly survey shall include 

observation of all exposed transfer points and fabric filter 

baghouses in the fly ash handling system. The Permittee shall 

keep a record of the name of the observer, the date on which the 

observation was made, and the results of the observation. 

b. If the observer sees a plume from a fly ash handling system 

fabric filter baghouse that on an instantaneous basis appears to 

exceed the applicable opacity standard, the observer shall if 

possible take a six-minute Method 9 observation of the plume. 

c. If the six-minute opacity of the plume from the fly ash handling 

system baghouse exceeds 10 percent, the Permittee shall do the 

following: 

(1) Adjust or repair the controls or equipment to reduce 

opacity to below 10 percent; and 

(2) Report it as an excess emission in accordance with 

Condition XII.A of Attachment “A” of this permit. 

d. If the six-minute opacity of the plume from the fly ash handling 

system baghouse is less than the applicable opacity standard, the 

observer shall make a record of the following: 
Permit #53418 111 of 131 August 15, 2012 

Tucson Electric Power-SGS 

(1) Date and time of the test; and 

(2) The results of the Method 9 observation. 

e. If the observer sees a plume from a fly ash handling system 

emission point other than a fabric filter baghouse that on an 

instantaneous basis appears to exceed the applicable opacity 

standard in Condition XII.B.1.a, the observer shall if possible 

take a six-minute Method 9 observation of the plume. 

f. If the six-minute opacity of the plume from the fly ash handling 

system emission point exceeds the applicable opacity standard in 

Condition XII.B.1.a, the Permittee shall: 

(1) Adjust or repair the controls or equipment to reduce 

opacity to below the opacity standard in Condition 

XII.B.1.a; and 

(2) Report it as an excess emission in accordance with 

Section XII.A of Attachment “A” of this permit. 

g. If the six-minute opacity of the plume from the fly ash handling 

system emission point is less than the applicable opacity 

standard in condition XI.B.1.a, the observer shall make a record 

of the: 

(1) Date and time of the test; and 

(2) The results of the Method 9 observation. 

2. Particulate Matter 

The Permittee shall maintain records of emissions related maintenance 

performed on the fabric filter baghouses. [A.A.C. R18-2-306.A.3.c] 

E. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2-702.B.1, -730.A.1 and B. 

XIII. ACTIVATED CARBON SILO 

Particulate Matter and Opacity 

A. Emission Limitations 

1. The Permittee shall not cause, allow or permit the opacity of visible 

emissions exiting from the activated carbon silo to exceed 20 percent as 

measured by EPA Reference Method 9. [A.A.C. R18-2-702.B.1]
Permit #53418 112 of 131 August 15, 2012 

Tucson Electric Power-SGS 

2. The Permittee shall not cause, allow or permit the emission of 

particulates matter from the activated carbon silo into the atmosphere in 

quantities greater than the amount calculated by the following equation: 

E = 4.10 * P0.67 

Where: 

E = the maximum allowable particulate emission rate in pounds-mass per 

hour 

P = the process weight rate in tons-mass per hour 

[A.A.C. R18-2-730.A.1.a] 

3. The total process weight from all similar units employing a similar type 

process shall be used in determining the maximum allowable emission of 

particulate matter. [A.A.C. R18-2-730.B]

B. Air Pollution Control Requirements 

At all times when the system is in operation, including periods of startup, 

shutdown, and malfunction (as defined in Condition #s I.D.8,12, and 14), the 

Permittee shall, to the extent practicable, maintain and operate a vent filter to 

capture particulate matter emissions associated with the activated carbon silo in 

a manner consistent with good air pollution control practices. [A.A.C. R18-2-306.A.2 and -331.A.3.e] 

C. Monitoring/Recordkeeping/Reporting Requirements 

Opacity Monitoring [A.A.C. R18-2-306.A.3.c] 

1. A certified Method 9 observer shall conduct a weekly visual survey of 

visible emissions from the activated carbon silo when it is in operation. 

The Permittee shall keep a record of the name of the observer, the date 

on which the observation was made, and the results of the observation. 

2. If the observer sees a plume that on an instantaneous basis appears to 

exceed the applicable opacity standard, the observer shall if possible take 

a six-minute Method 9 observation of the plume. 

3. If the six-minute opacity of the plume exceeds the applicable opacity 

standard, the Permittee shall do the following: 

a. Adjust or repair the controls or equipment to reduce opacity to 

below the applicable opacity standard; and 

b. Report it as an excess emission in accordance with Section XII.A 

of Attachment A of this permit. 

4. If the six-minute opacity of the plume is less than the applicable opacity 

standard, the observer shall make a record of the following: 
Permit #53418 113 of 131 August 15, 2012 

Tucson Electric Power-SGS 

a. Date and time of the test; and 

b. The results of the Method 9 observation. 

D. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2-702.B.1, -730.A.1.a, and B. 

XIV. EVAPORATIVE WATER SPRAY SYSTEMS (EWS) 

A. General Requirements 

1. The Permittee shall maintain and operate, as appropriate, four 

evaporative water spray systems (EWS) at the Evaporative Ponds East 

and West (for Unit 3) and Evaporative Ponds 1, 2, and 3 (for Units 1 and 

2) to address any freeboard issues. [A.A.C. R18-2-402.A] 

2. The Permittee shall maintain and operate the EWS according to the 

manufacturer’s specifications. [A.A.C. R18-2-406.A.4] 

3. The Permittee shall not emit gaseous or odorous materials from 

equipment, operations or premises under his control in such quantities as 

to cause air pollution. [A.A.C. R18-2-730.D]

4. Materials including solvents or other volatile compounds, paints, acids, 

alkalis, pesticides, fertilizers and manure shall be processed, stored, used 

and transported in such a manner and by such means that they will not 

evaporate, leak, escape or be otherwise discharged into the ambient air so 

as to cause or contribute to air pollution. Where means are available to 

reduce effectively the contribution to air pollution from evaporation, 

leakage or discharge, the installation and use of such control methods, 

devices or other equipment shall be mandatory. [A.A.C. R18-2-730.F] 

5. Where a stack, vent or other outlet is at such a level that fumes, gas mist, 

odor, smoke, vapor or any combination thereof constituting air pollution 

is discharged to adjoining property, the Director may require the 

installation of abatement equipment or the alteration of such stack, vent 

or other outlet by the Permittee to a degree that will adequately dilute, 

reduce or eliminate the discharge of air pollution to adjoining property. 

[A.A.C. R18-2-730.G] 

6. Monitoring and Recordkeeping Requirements 

[A.A.C. R18-2-306.A.3.c and -306.A.4.a] 

a. At the end of each quarter the Permittee shall calculate the total 

hours of operation of each spray system for the preceding four 

quarters. 

b. The Permittee shall perform a quarterly inspection of each spray 

nozzle to ensure their proper functioning and physical integrity. 

The Permittee shall keep a record of the date and result of each 

inspection and any corrective action performed. 
Permit #53418 114 of 131 August 15, 2012 

Tucson Electric Power-SGS 

B. Opacity Limit [A.A.C. R18-2-702.B.1 and C]

The Permittee shall not cause or allow to be discharged into the atmosphere from 

the EWS any emissions which exhibits opacity greater than 20 percent, as 

determined by Method 9. If the presence of uncombined water is the only reason 

for an exceedance of the opacity standard, the exceedance shall not constitute a 

violation. 

C. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C. R18-2-702.B.1, C, -730.D, F, and G. 

XV. FUGITIVE DUST SOURCES 

A. Emission Limits and Standards 

Open Areas, Roadways & Streets, Storage Piles, and Material Handling 

1. The Permittee shall not cause, allow or permit visible emissions from 

open areas, roadways and streets, storage piles or material handling in 

excess of 40 percent opacity measured in accordance with the Arizona 

Testing Manual, Reference Method 9. [A.A.C. R18-2-614] 

2. The Permittee shall employ the following reasonable precautions to 

prevent excessive amounts of particulate matter from becoming airborne: 

a. For open areas, use approved dust suppressants, adhesive soil 

stabilizer, paving, covering, detouring, or wetting agents on, or 

bar access to open areas during construction operations, repair 

operations, demolition activities, clearing operations, and 

leveling operations, or when any earth is moved or excavated or 

other acceptable means. [A.A.C. R18-2-604.A]

b. For open areas, use approved dust suppressants, adhesive soil 

stabilizer, or paving on, or bar access to driveways, parking 

areas, and vacant lots where motor vehicular activity occurs or 

other acceptable means. [A.A.C. R18-2-604.B] 

c. For Roadways & Streets, use approved dust suppressants, 

temporary paving, detouring or wetting agents when a roadway 

is repaired, constructed, or reconstructed or by other reasonable 

means. [A.A.C. R18-2-605.A] 

d. For Roadways & Streets, use dust suppressants, spray bars, 

hoods, wetting agents, or cover the load adequately when 

transporting material likely to give rise to airborne dust or other 

reasonable precautions; [A.A.C. R18-2-605.B] 

e. For Material Handling, use spray bars, hoods, wetting agents, 

dust suppressants, or cover when crushing, handling, or 
Permit #53418 115 of 131 August 15, 2012 

Tucson Electric Power-SGS 

conveying material that is likely to give rise to airborne dust; [A.A.C. R18-2-606] 

f. For Storage Piles, adequately cover, or use wetting agents, 

chemical stabilization, or dust suppressants when stacking, 

piling, or otherwise storing organic or inorganic dust producing 

material; [A.A.C. R18-2-607.A] 

g. For Storage Piles, operate stacking and reclaiming machinery 

utilized at storage piles at all times with a minimum fall of 

material and with the use of spray bars and wetting agents; [A.A.C. R18-2-607.B] 

h. For Roadway & Site Cleaning Machinery, use wetting agents or 

dust suppressants before the cleaning of site, roadway, or alley. 

Earth or other material shall be removed from paved streets onto 

which earth or other material has been transported by trucking or 

earth moving equipment, erosion by water or by other means; or [A.A.C. R18-2-804.B] 

i. Any other method as proposed by the Permittee and approved by 

the Director. 

B. Air Pollution Control Equipment [A.A.C. R18-2-331.A.3.e and -406.A.4] 

[Material Permit Conditions are defined by underline and italics] 

1. The Permittee shall not cause, permit, or allow the ash haul road to be 

used by vehicular or non-vehicular traffic without the use of an effective 

oil and chip surface with appropriate load-bearing base as required to 

control dust emissions from the ash haul road.

2. The Permittee shall not cause, permit, or allow the ash haul road to be 

used by vehicular or non-vehicular traffic unless the ash haul road has 

been watered within the most recent 24 hours. This requirement does 

not apply in the event that the ash haul road has received measurable 

precipitation within the most recent 24 hours.

C. Monitoring/Recordkeeping/Reporting Requirements 

1. Open Areas, Roadways & Streets, Storage Piles, and Material Handling 

The Permittee shall maintain records of dates and type of control 

measures adopted pursuant to Condition XV.A.2. [A.A.C. R18-2-306.A.4] 

2. Bi-Weekly Opacity Survey 

a. Bi-Weekly Monitoring Requirements [A.A.C.R18-2-306.A.3.c] 

(1) A certified Method 9 observer shall conduct a bi-weekly 

survey of visible emissions from the fugitive dust 

sources. The Permittee shall keep a record of the name 
Permit #53418 116 of 131 August 15, 2012 

Tucson Electric Power-SGS 

of the observer, the date on which the 

observation/survey was conducted, and the results of the 

observation/survey. 

(2) If the observer sees a plume from a non-point source that 

on an instantaneous basis appears to exceed the 

applicable opacity standard, then the observer shall, if 

practicable, take a six-minute Method 9 observation of 

the plume. If the six-minute opacity of the plume is less 

than the applicable standard, the observer shall make a 

record of the: 

(a) Location, date, and time of the observation; and 

(b) The results of the Method 9 observation. 

(3) If the six-minute opacity of the plume exceeds the 

applicable opacity standard, then the Permittee shall: 

(a) Adjust or repair the controls or equipment to 

reduce opacity to below the applicable standard; 

and 

(b) Report it as an excess emission under Section 

XII.A of Attachment” A”. [A.A.C.R18-2-306.A.3.c] 

3. Dust Control Practice 

The Permittee shall maintain and implement a site dust control practice. 

The Permittee shall keep the dust control practice readily available for 

inspection. The dust control practice will be a living document that will 

be updated as needed to allow for practical changes at the facility. 

D. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2- 604.A, B, -605, -606, -607, -614, and -804.B. 

XVI. ABRASIVE BLASTING 

A. Emission Limits and Standards 

1. The Permittee shall not cause or allow sandblasting or other abrasive 

blasting without minimizing dust emissions to the atmosphere through 

the use of good modern practices. Good modern practices include: 

[A.A.C. R18-2-726]

a. wet blasting; 

b. effective enclosures with necessary dust collecting equipment; or 
Permit #53418 117 of 131 August 15, 2012 

Tucson Electric Power-SGS 

c. any other method proposed by the Permittee and as approved by 

the Director. 

2. The Permittee shall not cause, allow or permit visible emissions from 

sandblasting or other abrasive blasting operations in excess of 20 percent 

opacity measured in accordance with EPA Reference Method 9. 

[A.A.C. R18-2-702.B.1] 

B. Monitoring/Recordkeeping/Reporting Requirements 

Each time an abrasive blasting project is conducted, the Permittee shall log in ink 

or in an electronic format, a record of the: [A.A.C. R18-2-306.A.3.c] 

1. The date the project conducted; 

2. The duration of the project; and 

3. Type of control measures employed. 

C. Permit Shield [A.A.C.R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2- 702.B.1 and -726. 

XVII. USE OF PAINTS 

A. Emission Limits and Standards 

While performing spray painting operations, the Permittee shall comply with the 

following requirements: 

1. The Permittee shall not conduct or cause to be conducted any spray 

painting operation without minimizing organic solvent emissions. Such 

operations other than architectural coating and spot painting, shall be 

conducted in an enclosed area equipped with controls containing no less 

than 96 percent of the overspray. [A.A.C. R18-2-727.A] 

2. The Permit shall not either: [A.A.C. R18-2-727.B] 

a. Employ, apply, evaporate or dry any architectural coating 

containing photochemically reactive solvents for industrial or 

commercial purposes; or 

b. Thin or dilute any architectural coating with a photochemically 

reactive solvent. 

3. For purposes of Conditions XVII.A.2 and 5, a photochemically reactive 

solvent shall be any solvent with an aggregate of more than 20 percent of 

its total volume composed of the chemical compounds classified in 

paragraphs a. through c. of this subsection, or which exceeds any of the 

following percentage composition limitations, referred to the total 

volume of solvent: [A.A.C. R18-2-727.C] 
Permit #53418 118 of 131 August 15, 2012 

Tucson Electric Power-SGS 

a. A combination of the following types of compounds having an 

olefinic or cycle-olefinic type of unsaturation - hydrocarbons, 

alcohols, aldehydes, esters, ethers, or ketones: five percent. 

b. A combination of aromatic compounds with eight or more 

carbon atoms to the molecule except ethylbenzene: eight percent. 

c. A combination of ethylbenzene, ketones having branched 

hydrocarbon structures, trichloroethylene or toluene: 20 percent. 

4. Whenever any organic solvent or any constituent of an organic solvent 

may be classified from its chemical structure into more than one of the 

groups or organic compounds described in Conditions XVII.A.3, it shall 

be considered to be a member of the group having the least allowable 

percent of the total volume of solvents. [A.A.C. R18-2-727.D] 

5. Visible emissions from spray painting operations shall not have opacity 

greater than 20 percent, measured in accordance with EPA Reference 

Method 9. [A.A.C. R18-2-702.B.1] 

B. Monitoring/Recordkeeping/Reporting Requirements 

1. Each time a spray painting project is conducted, the Permittee shall keep 

a record of the following: [A.A.C. R18-2-306.A.3.c] 

a. The date the project was conducted; 

b. The duration of the project; 

c. Type of control measures employed; and 

d. Material Safety Data Sheets for all paints and solvents used in 

the project. 

2. Architectural coating and spot painting projects shall be exempt from the 

recordkeeping requirements of Condition XVII.B.1. 

C. Permit Shield [A.A.C. R18-2-325]

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R18-2-702.B.1, -727, and SIP Provision R9-3-527.C. 

XVIII. SOLVENT CLEANING / DEGREASING, DIPPING OPERATIONS 

A. Emission Limits and Standards [A.A.C. R18-2-730.F] 

The Permittee shall process, store, use, and transport materials including solvents 

or volatile compounds in such a manner and by such means that they will not 

evaporate, leak, escape, or be otherwise discharged into the atmosphere so as to 

cause or contribute to air pollution. Where means are available to reduce 
Permit #53418 119 of 131 August 15, 2012 

Tucson Electric Power-SGS 

effectively the contribution to air pollution from evaporation, leakage, or 

discharge, the installation and usage of such control methods, devices, or 

equipment shall be mandatory.

B. Permit Shield [A.A.C.R18-2-325] 

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2-730.F. 

XIX. MOBILE SOURCES 

A. Emission Limits and Standards 

1. Classification [A.A.C. R18-2-801]

The requirements of this condition are applicable to mobile sources 

which either move while emitting air contaminants or are frequently 

moved during the course of their utilization but are not classified as 

motor vehicles, agricultural vehicles, or are agricultural equipment used 

in normal farm operations. Mobile sources shall not include portable 

sources as defined in A.A.C. R18-2-101.84. 

2. Off-road Machinery [A.A.C. R18-2-802]

The Permittee shall not cause, allow, or permit to be emitted into the 

atmosphere from any off-road machinery, smoke for any period greater 

than ten consecutive seconds, the opacity of which exceeds 40 percent. 

Visible emissions when starting cold equipment shall be exempt from 

this requirement for the first ten minutes. Off-road machinery shall 

include trucks, graders, scrapers, rollers and other construction and 

mining machinery not normally driven on a completed public roadway. 

3. Roadway and Site Cleaning Machinery [A.A.C. R18-2-804.A] 

The Permittee shall not cause, allow, or permit to be emitted into the 

atmosphere from any roadway and site cleaning machinery smoke or 

dust for any period greater than ten consecutive seconds, the opacity of 

which exceeds 40 percent. Visible emissions when starting cold 

equipment shall be exempt from this requirement for the first ten 

minutes. 

B. Monitoring/Recordkeeping/Reporting Requirements 

The Permittee shall keep a record of all emissions related maintenance activities 

performed on all mobile sources (as defined at Condition XIX.A.1) that are 

stationed at the facility. [A.A.C. R18-2-306.A.3.c] 
Permit #53418 120 of 131 August 15, 2012 

Tucson Electric Power-SGS 

C. Permit Shield [A.A.C. R18-2-325] 

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2-801, -802, and -804.A. 

XX. DEMOLITION/RENOVATION 

A. Emission Limits and Standards 

The Permittee shall comply with all applicable requirements of 40 CFR Part 61 

Subpart M (National Emissions Standards for Hazardous Air Pollutants -

Asbestos). [A.A.C. R18-2-1101.A.8] 

B. Monitoring/Recordkeeping/Reporting Requirements 

The Permittee shall comply with all applicable monitoring, recordkeeping, and 

reporting requirements of 40 CFR Part 61 Subpart M (National Emissions 

Standards for Hazardous Air Pollutants - Asbestos). The required records 

include the “NESHAP Notification for Renovation and Demolition Activities” 

form and all supporting documents. [A.A.C. R18-2-1101.A.8] 

C. Permit Shield [A.A.C. R18-2-325] 

Compliance with the Conditions of this Section shall be deemed compliance with 

A.A.C.R-18-2-1101.A.8.
Permit #53418 121 of 131 August 15, 2012 

Tucson Electric Power-SGS 

ATTACHMENT “C”: EQUIPMENT LIST 

Air Quality Control Permit No. 53418 for 

TUCSON ELECTRIC POWER COMPANY – Springerville Generating Station 

Equipment Description Size Serial Number Model DATE OF 

Commercial 

Operation/

Manufacture

Applicability

of NSPS 

Applicability

of NESHAP

Unit 1 

Boiler 

Tangentially 

fired, single 

drum, 

reheat, 

controlled 

circulation 

sub critical 

steam 

generating 

unit 

387 MW, net SGS-8-1-004 

Combustion 

Engineering 

Inc. 

1/30/78 

(Commenced 

construction) 

5/1/85 

(Commercial 

operating) 

Yes, 40 CFR 

Subpart D No 

Unit 2 

Boiler 

Tangentially 

fired, single 

drum, 

reheat, 

controlled 

circulation 

sub critical 

steam 

generating 

unit 

390 MW, net SGS-8-1-004 

Combustion 

Engineering 

Inc. 

1/30/78 

(Commenced 

construction) 

6/1/90 

(Commercial 

operating) 

Yes, 40 CFR 

Subpart D No 

Unit 3 

Boiler 

Steam 

generating 

unit wall 

fired, 

natural 

circulation, 

sub critical, 

single drum 

417 MW, net 65-100019-00 Foster 

Wheeler 

...7/20/2006 

(Commenced 

operating) 

Yes, 40 CFR 

Subpart Da No 
Permit #53418 122 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial Number Model DATE OF 

Commercial 

Operation/

Manufacture

Applicability

of NSPS 

Applicability

of NESHAP

Equipment

Unit 4 

Boiler 

Steam 

generating 

unit wall 

fired, 

natural 

circulation, 

sub critical, 

single drum 

426 MW, net 65-119154-00 Foster 

Wheeler 

...12/17/2009 

(Commenced 

operating) 

Yes, 40 CFR 

Subpart Da NA 

Auxiliary 

Boiler 

Oil fired 

with 

superheater 

for two unit 

cold start-up 

113 

MMBtu/hr AS-5-2-001 Zurn 

Industries 

01/30/78 

(Commenced 

construction) 

1984 

(Commercial 

operating 

No NA 

Emergency 

diesel 

generator 

Unit 1 and 

Unit 2 

Diesel 

generator 

with 650 

gallon fuel 

oil tank 

1300 HP 16E0007459 

Neil Detriot 

– 91637306 

5/1/85 

(Commercial 

operating) 

No NA 

Emergency 

Diesel Fire 

Pump for 

Unit 1 and 

Unit 2 

Cummins 4 

cycle, inline, 6 

cylinder 

diesel 

340 HP @ 

2100 rpm 60507610 NT855-F4 1999 (manufacture) No Yes, Subpart ZZZZ 

Emergency 

Diesel Fire 

Pump for 

Unit 3 

Caterpillar 

375 HP 6TB22509 3406 2004 

(manufacture) No Yes, Subpart ZZZZ 

Emergency 

Diesel Fire 

Pump for 

Unit 4 

John Deere 

4 cycle, inline, 4 

cylinder 

diesel 

475 HP RG6125A016084 6125AF001 2007 

(manufacture) 

Yes, Subpart 

IIII 

Yes, Subpart 

ZZZZ 

Cooling 

Tower 1 

Steam unit 

cooling 

tower 

Recirculation 

rate 

176,000 

gal/min 

PGS-9-1 NA NA No NA 
Permit #53418 123 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial Number Model DATE OF 

Commercial 

Operation/

Manufacture

Applicability

of NSPS 

Applicability

of NESHAP

Equipment

Cooling 

Tower 2 Steam unit 

cooling 

tower 

Recirculation 

rate 

176,000 

gal/min 

PGS-9-1 NA NA No NA 

Cooling 

Tower 3 

Steam unit 

cooling 

tower 

Recirculation 

rate 200,000 

gal/min 

ICT8463-

CWHH31-5-11-

28 

CWHH31-5-

11-28 NA No NA 

Cooling 

Tower 4 

Steam unit 

cooling 

tower 

Recirculation 

rate 200,000 

gal/min 

ICT-CW8832-5-

28-11 

CW8832-5-

28-11 NA No NA 

Coal 

Preparation 

Plant 

Storage 

silos, 

unloading 

system, 

sampling 

system, 

crushers, 

conveyor, 

transfer 

points, 

transfer 

towers, and 

reclaim 

8,200,000 

tons/yr 

Figure 1-1 

Site Layout 

NA NA Yes, 40 CFR 

Subpart Y NA 

Lime 

Handling 

Unit 1 and 

Unit 2 

Storage 

silos, lime 

unloading, 

lime feed 

bins 

166,400 

ton/yr 

AS-6-1-001 

AS-6-2-001 

AS-6-3-001 

NA NA No NA 
Permit #53418 124 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial Number Model DATE OF 

Commercial 

Operation/

Manufacture

Applicability

of NSPS 

Applicability

of NESHAP

Equipment

One hopper 

and three 

completely 

enclosed 

belts 

- 24” wide 

by 256’7 

1/16” long 

-30” wide by 

121’10 9/16” 

long 

-24” wide by 

31’4 

1/16” long 

NA 

Sveldala 

Eastern 

Made 

NA No NA 

Lime 

Handling 

Unit 3 and 

Unit 4 

Storage 

silos, lime 

unloading, 

lime feed 

bins 

62,400 ton/yr NA NA NA No NA 

Ash 

Handling 

Unit 1 Unit 

2 

-- -- NA NA NA No NA 

Ash 

Handling 

Unit 3 Unit 

4 

Storage 

silos, ash 

truck 

loading 

836,182 

ton/yr NA NA NA No NA 

DCL CFM 

Dust Filter 

Modlue 

Pulse-jet 

cleaned, 

cartridge 

type in-line 

dust 

collector 

Filtering 

Area: 

329 sf. 

NA 

CFM 330 

DCL: 

distributed 

by Process & 

Power/Texas, 

Inc. 

TBD 

NA NA 

Nonpoint 

sources 

-- -- -- -- -- NA NA 

Sand 

Blasting 

-- -- -- -- -- NA NA 
Permit #53418 125 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial Number Model DATE OF 

Commercial 

Operation/

Manufacture

Applicability

of NSPS 

Applicability

of NESHAP

Equipment

Spray 

Painting 

-- -- -- -- -- NA NA 

Mobile 

Sources 

-- -- -- -- -- NA NA 

Demolition 

and 

Renovation 

-- -- -- -- -- 

NA NA 

Air 

Conditioner 

Maintenance 

-- -- -- -- -- 

NA NA 

Continuous Emission Monitors 

Steam

Unit

NOx Monitor SO2 Monitor CO Monitor Diluent Monitor Opacity Monitor Flow Monitor

Unit 1 NOx -

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

SO2-

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

NA 

CO2 – 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Opacity - 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Flow – 

Installed/Certified

PLC – 

Installed/Certified

DAHSInstalled/Certified

Unit 2 NOx -

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

SO2-

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

NA 

CO2 – 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Opacity - 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Flow – 

Installed/Certified

PLC – 

Installed/Certified

DAHSInstalled/Certified
Permit #53418 126 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Steam NOx Monitor SO2 Monitor CO Monitor Diluent Monitor Opacity Monitor Flow Monitor

Unit

Unit 3 NOx -

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

SO2-

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

COInstalled/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

CO2 – 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Opacity - 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Flow – 

Installed/Certified

PLC – 

Installed/Certified

DAHSInstalled/Certified

Unit 4 NOx -

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

SO2-

Installed/Certified 

PLCInstalled/Certified 

DAHSInstalled/Certified 

COInstalled/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

CO2 – 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Opacity - 

Installed/Certified

PLCInstalled/Certified

DAHSInstalled/Certified

Flow – 

Installed/Certified

PLC – 

Installed/Certified

DAHSInstalled/Certified

Air Pollution Control Equipment 

Equipment Description Size Serial

Number 

Model Date of 

Commercial 

Operation/

Manufacture

Sulfur Dioxide 

Removal System 

for Unit 1 

Dry flue gas 

desulfurization for 

Steam Unit 1 

150 GPM each rotary atomizer 

(3), 11,500 RPM, 600 HP drive 

motor with a 2 HP oil pump 

motor per unit 

 Joy/Niro is 

now owned by 

B&W 

1/30/78 

(Commenced 

construction) 

Sulfur Dioxide 

Removal System 

for Unit 1 

Dry flue gas 

desulfurization for 

Steam Unit 1 

(1) 150 gpm,11,500 RPM, 

drive, 600 HP drive motor with 

a 2 HP oil pump motor per unit

N/A B&W Nov. 2004 

Sulfur Dioxide 

Removal System 

for Unit 2 

Dry flue gas 

desulfurization for 

Steam Unit 2 

150 GPM each rotary atomizer 

(3), 11,500 RPM, 600 HP drive 

motor with a 2 HP oil pump 

motor per unit 

 Joy/Niro is 

now owned by 

B&W 

1/30/78 

(Commenced 

construction) 

Sulfur Dioxide 

Removal System 

for Unit 2 

Dry flue gas 

desulfurization for 

Steam Unit 2 

(1) 150 gpm,11,500 RPM, 

drive, 600 HP drive motor with 

a 2 HP oil pump motor per unit

N/A B&W April 2005 
Permit #53418 127 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial

Number 

Model Date of 

Commercial 

Operation/

Manufacture

Equipment

Sulfur Dioxide 

Removal System 

for Unit 3 

Dry flue gas 

desulfurization for 

Steam Unit 3 

(6) 34 gpm,12,185 RPM, drive, 

250 HP drive motor NA Alstom 

July 2006 

Sulfur Dioxide 

Removal System 

for Unit 4 

Dry flue gas 

desulfurization 

(6) 34 gpm,12,185 RPM, drive, 

250 HP drive motor NA Alstom 

December 2009 

Particulate 

Matter Removal 

System for 

Unit 1 

Baghouses 1,320,000 acfm at 160 °F (2) 

NA Joy 

1/30/78 

(Commenced 

construction) 

Particulate 

Matter Removal 

System for Unit 

2 

Baghouses 1,320,000 acfm at 160° F (2) 

NA Joy 

1/30/78 

(Commenced 

construction) 

Particulate 

Matter Removal 

System for Unit 

3 

Fabric filter 

baghouse 

1,705,000 acfm at 175F inlet 

NA Alstom 

July 2006 

Particulate 

Matter Removal 

System for Unit 

4 

Fabric filter 

baghouse 

1,705,000 acfm at 175F inlet LKP2x8SS5x26.5-

IP2x18x25 

(900) 

LKP2x8SS5x26.5-

IP2x18x25 

(900) 

December 2009 

Unloading 

Transfer Tower 

Collector 

12,000 cfm at 70°F 09285A JohnsonMarch Model 

#PCT 12-10 

Secondary Crusher 

Enclosure Dust 

Collector (DC-2) 

27,950 cfm at 70°F 002858 JohnsonMarch Model 

#PCT 13-17 

Sampler Enclosure 

Dust Collector 

9,400 cfm at 70° F 09285C JohnsonMarch Model 

#PCT 10-10 

01/30/78 

(Commenced 

construction) 
Permit #53418 128 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial

Number 

Model Date of 

Commercial 

Operation/

Manufacture

Equipment

Silos Feed Tower 

Collector (DC-4) 

27,950 cfm at 70°F 09285D JohnsonMarch Model 

#PCT 10-13-

17 

Silo Feed Tower 

Collector (DC-4A) 

27,950 cfm at 70°F 09285B JohnsonMarch Model 

#PCT 10-13-

17 

Unit 1 & 2 – Dust 

Processing Center 

Dust Collector 

2,325 cfm Airtrol Airtrol, Inc. 

68BRST72 

TBD 

Unit 3 - Transfer 

Tower # 1& 2 

Dust Collector 

24,000 cfm 9-FC-MK001 Airtrol, Inc. 

276RRWT144 

July 2006 

Unit 3 - Transfer 

Tower # 3 Dust 

Collector 

18,750 cfm 9-FC-MK006 Airtrol, Inc. 

232RRWT144 

July 2006 

Coal Handling 

System 

Unit 3 - Transfer 

Tower # 4 / Silo 

Dust Collector 

35,075 cfm 9-FC-MK016 Airtrol, Inc. 

428RRWT144 

July 2006 

Unit 3 - Crusher 

Tower Dust 

Collector 

34,975 cfm 9-FC-MK012 Airtrol, Inc. 

428RRWT144 

July 2006 

Unit 4 – Silo Dust 

Collector 

22850 cfm 4-fc-mk212 AirCure Dec 2009 

Unit 4 – Transfer 

Tower Dust 

Collector 

13550 cfm 4-fc-mk-172 AirCure Dec 2009 

Unit 4 – Transfer 

Tower Dust 

Collector 

26750 cfm 4-fc-mk-162 AirCure Dec 2009 

Coal Handling 

System 

Unit 4 – Dust 

Processing Center 

Dust Collector 

24700 cfm 4-fc-mk-022 AirCure Dec 2009 
Permit #53418 129 of 131 August 15, 2012 

Tucson Electric Power-SGS 

Description Size Serial

Number 

Model Date of 

Commercial 

Operation/

Manufacture

Equipment

Lime Silos 

Collector 

-- 345-78-4-

3005-00 

Fuller Co. 01/30/78 

(Commenced 

construction 

Baghouses at 

Water Treatment 

Silos (4) 

-- 3710(1); 

3710(2) 

3710(3); 

3710(4) 

EVO Corp. 

Model 

#84WBO48C 

Lime Handling 

System- Unit 1 

and Unit 2 

Filter Baghouse 15,000 ACFM -- -- 1999 

Lime Silos 

Collector 

500 cfm 66315-001-1 MAC MTV2 July 2006 

Lime Handling 

System- Unit 3 

and Unit 4 

Baghouses at 

Water Treatment 

Silos (2) 

 6101 and 

6600 

84-BF-042-C July 2006 And 

Dec 2009 

Drift Eliminator 

on Cooling 

Tower Unit 3 

High-efficiency 

drift eliminator 

11 Cells 2”High, 48’ x 48’ N/A CDX-080 

Brentwood 

July 2006 

Drift Eliminator 

on Cooling 

Tower Unit 4 

High efficiency 

drift eliminator 

11 Cells 2”High, 48’ x 48’ N/A CDX-080 

Brentwood 

Dec 2009 

Ash Handling 

System Units 3 

Units 3 Fly Ash 

Silo Dust 

Collector 

10,271 ACFM N/A IAC-144TBBV1-132:S6 July 2006 

Ash Handling 

System Units 4 

Units 4 Fly Ash 

Silo Dust 

Collectors A&B 

6,248 ACFM N/A IAC-120TBBVT-100:S6 Dec 2009 

Mercury 

Removal System 

Unit 4 

Activated Carbon 

Injection 

120 cuft per hour MT1600 07-3026 12/17/2009 

Four – 

Evaporative 

Water Spray 

Systems 

Evaporative Water 

Sprays on Ponds 

1, 2, & 3 for 

freeboard control. 

900 gpm per unit x 4 pumps B738FO78-1, 

B738FO78-2, 

B738FO79-1, 

B738FO79-2 

3796 March 2009 
Permit #53418 130 of 131 August 15, 2012 

Tucson Electric Power-SGS 

ATTACHMENT "D": PHASE II ACID RAIN PROVISIONS

Air Quality Control Permit No. 53418 

For

TUCSON ELECTRIC POWER PLANT - Springerville Generating Station 

1. Statement of Basis 

Statutory and Regulatory Authorities: In accordance with Arizona Revised Statutes, Title 49, 

Chapter 3, Article 2, Section 426.N, and Titles IV and V of the Clean Air Act, the Arizona 

Department of Environmental Quality issues this Phase II Acid Rain Permit pursuant to Arizona 

Administrative Code, Title 18, Chapter 2, Article 3, Section 333 ( A.A.C. R18-2-333), “Acid 

Rain”. 

2. SO2 Allowance Allocations and NOx Requirements for each affected unit 

 2012 2013 2014 2015 2016 2017 

Unit 1 6099 6099 6099 6099 6099 6099 6099 

NOx limit Unit 1 shall be subject to the applicable emission limitation, under 

40 CFR 76.7(a)(1), of 0.40 lb/MMBtu of heat input on annual 

average basis. 

 2012 2013 2014 2015 2016 2017 

Unit 2 5765 5765 5765 5765 5765 5765 5765 

NOx limit Unit 2 shall be subject to the applicable emission limitation, under 

40 CFR 76.7(a)(1), of 0.40 lb/MMBtu of heat input on annual 

average basis. 
Permit #53418 131 of 131 August 15, 2012 

Tucson Electric Power-SGS 

 2012 2013 2014 2015 2016 2017 

Unit 3 NA NA NA NA NA NA NA 

NOx limit Unit 3 shall be subject to the applicable emission limitation, 

under 40 CFR 76.7(a)(1), of 0.40 lb/MMBtu of heat input on 

annual average basis. 

* The number of allowances allocated to Phase II affected units by U.S. EPA may change in a 1998 

revision to 40 CFR part 73 Tables 2, 3, and 4. In addition, the number of allowances actually held by 

an affected source in a unit account may differ from the number allocated by U.S. EPA. Neither of the 

aforementioned conditions necessitates a revision to the unit SO2 allowance allocations identified in 

this permit (See 40 CFR 72.84). 

 2012 2013 2014 2015 2016 2017 

Unit 4 NA NA NA NA NA NA NA 

NOx limit Unit 4 shall be subject to the applicable emission limitation, under 

40 CFR 76.7(a)(1), of 0.40 lb/MMBtu of heat input on annual 

average basis.

3. Comments, Notes and Justifications 

Tucson Electric has early-elected for NOx requirements on Unit 1 and Unit 2. 

4. Permit Application 

The Permittee, and any other owners or operators of the units at this facility, shall comply with 

the requirements contained in the attached acid rain permit application (OMB No. 2060-0258) 

signed by the Designated Representative Charles Komadina.