ARIZONA DEPARTMENT OF ENVIRONMENTAL QUALITY 

TV Renewal Permit No. 53399 Page 1 of 109 May 31, 2012 

APS-Cholla Generating Station 

AIR QUALITY CLASS I PERMIT 

COMPANY: Arizona Public Service Company

FACILITY: Cholla Generating Station 

PERMIT #: 53399 

DATE ISSUED: May 31, 2012

EXPIRY DATE: May 31, 2017

_____________________________________________________________________________________ 

SUMMARY 

This Class I, Title V Air Quality Renewal Permit is issued to Arizona Public Service Company for the 

continued operation of the Cholla Generating Station. The facility is located approximately two miles 

east of the town of Joseph City on Interstate 40, in Navajo County, Arizona, and approximately 200 miles 

northeast of Phoenix. This permit renews Permit #33500. 

The Cholla Power Plant operates four pulverized coal-fired, steam boilers which generate approximately 

1,160 megawatts of electricity. Each unit is a tangentially-fired, dry bottom furnace. Natural gas and 

diesel fuel are used as startup and stabilization fuels. Unit 4 is permitted to co-fire used oil/used oil fuel 

for energy recovery purposes. Unit 1, 3 and 4 are each equipped with fabric filter devices and Unit 2 is 

equipped with a mechanical dust collector for controlling particulate matter emissions. In addition, Unit 1 

is equipped with a tray tower absorber system, Unit 2 is equipped with a four module flooded-disk 

scrubbers and four absorber towers, and Units 3 and 4 have spray tower absorber for controlling sulfur 

dioxide (SO2) emissions. All four units are retrofitted with low-NOx burners (LNBs) and over-fire air 

systems to reduce NOx emissions. 

The Cholla Generating Station is classified as a Class I, Major Source, pursuant to Arizona 

Administrative Code (A.A.C.) R18-2-101.64. The potential emission rates of the following pollutants are 

greater than 100 tons per year: particulate matter, sulfur dioxide, nitrogen oxides, and carbon monoxide. 

The Cholla Power Plant is also subject to the Acid Rain Program of the Clean Air Act. This Class I 

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 

A.A.C. R18-2-101 et. seq. 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 terms 

and conditions in this permit are enforceable by the Administrator of the United States Environmental 

Protection Agency (U.S. EPA), except for those terms and conditions that have been designated as "State 

requirements". 
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APS-Cholla Generating Station 

TABLE OF CONTENTS 

ATTACHMENT “A”: GENERAL PROVISIONS.................................................................................. 4 

I. PERMIT EXPIRATION AND RENEWAL.................................................................................... 4 

II. COMPLIANCE WITH PERMIT CONDITIONS ........................................................................... 4 

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

 TERMINATION FOR CAUSE....................................................................................................... 4 

IV. POSTING OF PERMIT................................................................................................................... 5 

V. FEE PAYMENT .............................................................................................................................. 5 

VI. ANNUAL EMISSION INVENTORY QUESTIONNAIRE ........................................................... 5 

VII. COMPLIANCE CERTIFICATION ............................................................................................... 5 

VIII. CERTIFICATION OF TRUTH, ACCURACY, AND COMPLETENESS .................................... 6 

IX. INSPECTION AND ENTRY .......................................................................................................... 6 

X. PERMIT REVISION PURSUANT TO FEDERAL HAZARDOUS AIR POLLUTANT

 STANDARD.................................................................................................................................... 7 

XI. ACCIDENTAL RELEASE PROGRAM......................................................................................... 7 

XII. EXCESS EMISSIONS, PERMIT DEVIATIONS, AND EMERGENCY REPORTING ............... 7 

XIII. RECORD KEEPING REQUIREMENTS ..................................................................................... 11 

XIV. REPORTING REQUIREMENTS ................................................................................................. 11 

XV. DUTY TO PROVIDE INFORMATION....................................................................................... 11 

XVI. PERMIT AMENDMENT OR REVISION.................................................................................... 12 

XVII. FACILITY CHANGE WITHOUT REVISION ............................................................................ 12 

XVIII. TESTING REQUIREMENTS ....................................................................................................... 13 

XIX. PROPERTY RIGHTS.................................................................................................................... 14 

XX. SEVERABILITY CLAUSE .......................................................................................................... 14 

XXI. PERMIT SHIELD.......................................................................................................................... 14 

XXII. PROTECTION OF STRATOSPHERIC OZONE ......................................................................... 14 

XXIII. NSPS AND NESHAP REQUIREMENTS.................................................................................... 14 

ATTACHMENT “B” PERMIT SPECIFIC CONDITIONS................................................................. 15 

I. GENERAL REQUIREMENTS .................................................................................................... 15 

II. STEAM BOILER UNIT 1 ............................................................................................................ 17 

III. STEAM BOILER UNIT 2............................................................................................................. 28 

IV. STEAM BOILER UNIT 3............................................................................................................. 50 

V. STEAM BOILER UNIT 4............................................................................................................. 66 

VI. COOLING TOWERS 3 AND 4 .................................................................................................... 84 

VII. COAL PREPARATION PLANT .................................................................................................. 85

VIII. FLY ASH HANDLING FACILITY.............................................................................................. 87

IX. LIME HANDLING AND SLAKING ........................................................................................... 88 
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APS-Cholla Generating Station 

X. FUGITIVE DUST REQUIREMENTS.......................................................................................... 90 

XI. MOBILE SOURCE REQUIREMENTS........................................................................................ 91 

XII. OTHER PERIODIC ACTIVITY REQUIREMENTS .................................................................. 92 

XIII. INTERNAL COMBUSTION ENGINES ...................................................................................... 96 

XIV. MERCURY REQUIREMENTS ................................................................................................... 97

ATTACHMENT “C”: EQUIPMENT LIST......................................................................................... 100 

ATTACHMENT “D”: ACID RAIN PROVISIONS ............................................................................ 105 

ATTACHMENT “E”: COMPLIANCE ASSURANCE MONITORING.......................................... 106
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APS-Cholla Generating Station 

ATTACHMENT “A”: GENERAL PROVISIONS 

AIR QUALITY CONTROL PERMIT NO. 53399

FOR 

APS–CHOLLA 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 of Permit No. 

53399. 

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 -321.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. 

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. 
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APS-Cholla Generating Station 

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. 

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; 
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APS-Cholla Generating Station 

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

period covered by the certification, based on the methods or means designated in 

Condition VII.A.2 above. The certifications shall identify each deviation and 

take it 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 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]

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

authorized representative of the Director to: 

B. 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; 

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

under the conditions of the permit; 

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

pollution control equipment), practices, or operations regulated or required under the 

permit; 

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

assuring compliance with the permit or other applicable requirements; and 

F. 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 
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APS-Cholla Generating Station 

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 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]
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APS-Cholla Generating Station 

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 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 reasonable 

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 technology-based emission limitation under the permit, 

due to unavoidable increases in emissions attributable to the emergency. An 

emergency shall not include noncompliance to the extent caused by improperly 

designed equipment, lack of preventative maintenance, careless or improper 

operation, or operator error. 

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. 

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 
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APS-Cholla Generating Station 

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 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. 
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APS-Cholla Generating Station 

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; 

(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. 

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: 
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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(24); 

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 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. 
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APS-Cholla Generating Station 

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 maximum possible capacity 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. 

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 
TV Renewal Permit No. 53399 Page 14 of 109 May 31, 2012 

APS-Cholla Generating Station 

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. 

G. Report of Final Test Results 

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

within 45 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. 

XXIII. NSPS AND NESHAP REQUIREMENTS [40 CFR Part 60, Part 63] 

 For all equipment subject to a New Source Performance Standard/National Emissions Standards 

for Hazardous Air Pollutants, the Permittee shall comply with all applicable requirements 

contained in Subpart A of Title 40, Part 60 and Part 63 of the Code of Federal Regulations. 
TV Renewal Permit No. 53399 Page 15 of 109 May 31, 2012 

APS-Cholla Generating Station 

ATTACHMENT "B": SPECIFIC CONDITIONS 

AIR QUALITY CONTROL TITLE V PERMIT NO. 53399

FOR 

Arizona Public Service – Cholla Generating Station 

I. GENERAL REQUIREMENTS 

A. Definitions 

1. Startup for Steam Boiler Units 2, 3 and 4: Startup means the setting in operation 

of a steam boiler unit for any purpose. For opacity purposes, startup begins when 

any forced draft, induced draft, or booster induced draft fan of the unit is turned 

on for any purpose. [40 CFR 60.2] 

2. Shutdown for Steam Boiler Units 2, 3 and 4: Shutdown means the cessation of 

operation of a steam boiler unit for any purpose. For opacity purposes, shutdown 

begins when the unit begins to drop load to go off line and ends when all fans of 

the unit are turned off. [40 CFR 60.2] 

3. Malfunction for Steam Boiler Units 2, 3 and 4: Malfunction means any sudden 

and unavoidable failure of air pollution control equipment, process equipment or 

a process to operate in a normal and usual manner, but does not include failures 

that are caused by poor maintenance, careless operation or any other upset 

condition or equipment breakdown which could have been prevented by the 

exercise of reasonable care. [40 CFR 60.2] 

4. Boiler operating day means a 24-hour period during which fossil fuel is 

combusted in a steam generating unit for the entire 24 hours. [40 CFR 60.41a] 

B. For the purpose of this permit, unless otherwise specified in the applicable standards, for 

any facility subject to the new source performance standards 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 subsection 

“Performance Testing Requirements” of each applicable section. [40 CFR 60.11(a) and 8(b)] 

C. For the purpose of this permit, for any facility subject to the new source performance 

standards from 40 CFR Part 60, compliance with the 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 and the Administrator, unless the 

Permittee elects to submit continuous opacity monitoring system data for compliance 

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

D. For the purpose of submitting compliance certifications or establishing whether or not the 

Permittee has violated or is in violation of any new source performance standards from 

40 CFR Part 60, subsumed under this attachment, nothing in this attachment 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)] 
TV Renewal Permit No. 53399 Page 16 of 109 May 31, 2012 

APS-Cholla Generating Station 

E. For the purpose 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 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.c and 40 CFR 60, Appendix A, Method 9, Section 2.5] 

F. The Permittee shall have on staff a person that is certified in EPA Reference Method 9. [A.A.C. R18-2-306.A.3.c] 

G. Within fourteen (14) calendar days after the compliance certifications required by Section 

VII of Attachment "A" have been submitted, the Permittee shall submit summary reports 

of all monitoring activities required in this attachment performed in the six months prior 

to the date of the report. [A.A.C. R18-2-306.A.5.a] 

H. For the purposes of this permit, Visible Emissions Observation Procedure shall refer to 

the following methodology: 

1. The Permittee shall continue to comply with the approved visual observation 

plan. The observation plan shall identify a central lookout station or multiple 

observation points, as appropriate, from where point and/or non-point sources, 

and where applicable, fugitive emissions, shall be monitored. When multiple 

observation points are used, all the point and/or non-point sources, and where 

applicable, fugitive emissions, associated with each observation point shall be 

specifically identified within the observation plan. 

2. A certified EPA Reference Method 9 observer shall conduct a visual survey of 

visible emissions from point or non-point sources, and where applicable, fugitive 

emissions, in accordance with the observation plan, under normal representative 

operating conditions. The survey shall be conducted at the frequency specified in 

the permit condition that refers to this procedure. The Permittee shall keep a 

record of the name of the observer, the date and time on which the observation 

was made, the location(s) of the observation, and the results of the observation. 

3. If the observer sees a plume from a point or non-point source or a fugitive 

emissions source that on an instantaneous basis appears to exceed the applicable 

opacity standard, then the observer shall, if practicable, take a six-minute EPA 

Reference Method 9 observation of the plume. 

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: 

a. Location, date, and time of the observation; 

b. The results of the EPA Reference Method 9 observation; and 

c. The name of the observer. 

5. If the six-minute opacity of the plume exceeds the applicable opacity standard, 

then the Permittee shall do the following: 

a. Adjust or repair the controls or equipment to reduce opacity to below the 

applicable opacity standard; 

b. Record corrective actions; 
TV Renewal Permit No. 53399 Page 17 of 109 May 31, 2012 

APS-Cholla Generating Station 

c. Report as an excess emission in accordance with Section XII of 

Attachment “A” of this permit; and 

d. Conduct a six-minute EPA Reference Method 9 observation reading 

within 48 hours after taking corrective action. The results of this 

observation including date, time, name of the observer, and location shall 

be recorded. 

6. Any changes to the observation plan shall be made only with the prior approval 

of the Director. 

I. The conditions of this attachment shall apply to equipment identified in Attachment “C” 

of this permit. In the event that after the date of permit issuance, the Permittee identifies 

pollutant emitting equipment or air pollution control equipment existing at the plant at the 

time of permit issuance, but not included in the permit application for this permit, or if 

the Permittee identifies errors in Attachment “C” of this permit, the Permittee shall 

follow the appropriate administrative procedures as set forth in Article 3 of Title 18, 

Chapter 2 of the Arizona Administrative Code to include such equipment in the permit or 

to correct such errors. [A.A.C. R18-2-304.G] 

II. STEAM BOILER UNIT 1 

A Applicability 

 This section applies to Unit 1 boiler as described in Attachment “C” of this permit. 

B. Fuel Limitation 

The Permittee shall burn only the following fuels in Steam Boiler Unit 1: 

1. Coal; 

2. Natural Gas for startup and stabilization. 

[Installation Permit No. 1002]

C. Particulate Matter & Opacity 

1. Emission Limits/Standards 

a. Opacity 

 The Permittee shall not cause, allow or permit to be emitted into the 

atmosphere any plume or effluent from the stack of Steam Boiler Unit 1, 

the opacity of which exceeds 20 percent, measured in accordance with 

EPA Reference Method 9. Where the presence of uncombined water is 

the only reason for an exceedance of the visible emissions requirement, 

such exceedance shall not constitute a violation. [A.A.C. R18-2-702.B.3 and C] 

b. Particulate Matter 

 The Permittee shall not cause, allow or permit the emission of particulate 

matter from the stack of Steam Boiler Unit 1 in excess of the amounts 

calculated by the following equation and rounded off to two decimal 

places: 

 

 E = 1.02 Q0.769 
TV Renewal Permit No. 53399 Page 18 of 109 May 31, 2012 

APS-Cholla Generating Station 

 Where: 

E = the maximum allowable particulate matter emissions rate in 

pounds-mass per hour 

Q = the heat input in million Btu per hour [A.A.C. R18-2-703.C.1 and D] 

c. Definition of Heat Input 

For the purpose of Conditions II.C.1.b of this Attachment, “heat input” is 

defined as the aggregate heat content of all fuels whose products of 

combustion pass through a stack or other outlet. The heat content of 

solid fuel shall be determined in accordance with A.A.C. R18-2-311. 

[A.A.C. R18-2-703.B] 

2. Air Pollution Control Requirements 

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

malfunction, to the extent practicable, operate and maintain Steam Boiler Unit 1 

and the fabric filter control device in a manner consistent with good air pollution 

control practice for minimizing particulate matter emissions. The Permittee shall 

inspect and maintain the fabric filter control device in accordance with 

manufacturer specifications. [A.A.C. R18-2-306.A.2 and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

3. Monitoring & Recordkeeping Requirements 

 Continuous Monitoring for Opacity 

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

monitoring system (COMS) for monitoring opacity at the fabric filter 

baghouse outlet of Steam Boiler Unit 1 [A.A.C. R18-2-313, A.A.C. R18-2-331.A.3.c]

 [Material Permit Condition identified by underline and italics] 

b. The COMS shall meet the following requirements under 40 CFR 60, 

Appendix B, Performance Specification 1, Specification and Test 

Procedures for Opacity Continuous Emission Monitoring Systems in 

Stationary Sources [A.A.C. R18-2-313.D.1.a] 

(1) Apparatus 

(2) Installation Specifications 

(3) Design and Performance Specifications 

(4) Design Specifications Verification Procedure 

(5) Performance Specifications Verification Procedure 

(6) Equations 

c. Quality Assurance Requirements 

i. Calibration Checks 

The Permittee shall record the zero and span drift in accordance 
TV Renewal Permit No. 53399 Page 19 of 109 May 31, 2012 

APS-Cholla Generating Station 

with the method prescribed by the manufacturer's recommended 

zero and span check at least once daily unless the manufacturer 

has recommended adjustments at shorter intervals, in which case 

such recommendations shall be followed. [A.A.C. R18-2-313.D.6] 

ii. Zero and Span Drift Adjustments 

(1) The Permittee shall adjust the zero or span whenever the 

24 hour zero drift or 24 hour calibration drift limits of 

2% opacity are exceeded. [A.A.C. R18-2-313.D.6] 

(2) The system shall allow for the amount of excess zero 

and span drift measured at the 24-hour interval checks to 

be recorded and quantified. [A.A.C. R18-2-313.D.6] 

(3) The optical surfaces exposed to the effluent gases shall 

be cleaned prior to performing the zero and span drift 

adjustments except that for systems using automatic zero 

adjustments. [40 CFR 60, Appendix B, PS1, 5.1.6] 

(4) The optical surfaces shall be cleaned when the 

cumulative automatic zero compensation exceeds 4% 

opacity. [40 CFR 60, Appendix B, PS1, 5.1.7] 

iii. Minimum Frequency of Operation 

Except during periods of system breakdowns, repairs, calibration 

checks, and zero and span adjustments, the COMS shall be in 

continuous operation and shall complete a minimum of one 

cycle of sampling and analyzing for each successive 15-second 

period and one cycle of data recording for each successive 6-

minute period. [A.A.C. R18-2-313.E.2]

iv. Data Reduction Procedures 

 

(1) The Permittee shall reduce all data from the COMS to 6-

minute averages. Six-minute opacity averages shall be 

calculated from 24 or more data points equally spaced 

over each 6-minute period. 

(2) 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 Condition. An arithmetic 

or integrated average of all data may be used. 

[A.A.C. R18-2-313.E] 

d. The Permittee shall comply with all the recordkeeping requirements of 

40 CFR Part 75 Subparts F. 

 [A.A.C. R18-2-306.A.4 and 5]

4. Reporting Requirements 

a. Quarterly Reporting Requirements 

i. The Permittee shall submit to the Director a written report of all 

emission exceedances for each calendar quarter and the nature 
TV Renewal Permit No. 53399 Page 20 of 109 May 31, 2012 

APS-Cholla Generating Station 

and cause of the exceedances, if known, postmarked by the 30th 

day following the end of each calendar quarter. The averaging 

period used for data reporting shall correspond to the averaging 

period specified in the emission standard. The required report 

shall include, as a minimum, the data stipulated in this 

subsection. [A.A.C. R18-2-313.E.1] 

ii. For opacity measurements, the summary shall consist of the 

magnitude in actual percent opacity of all six minute opacity 

averages greater than any applicable standards for each hour of 

operation of the facility. Average values may be obtained by 

integration over the averaging period or by arithmetically 

averaging a minimum of four equally spaced, instantaneous 

opacity measurements per minute. Any time periods exempted 

shall be deleted before determining any averages in excess of 

opacity standards. [A.A.C. R18-2-313.E.2] 

iii. The date and time identifying each period during which the 

continuous emission monitoring system was inoperative, except 

for zero and span checks and the nature of system repair or 

adjustment shall be reported. The Director may require proof of 

continuous emission monitoring system performance whenever 

system repairs or adjustments have been made. 

 [A.A.C. R18-2-313.E.4] 

b. Emission Deviations Reporting Requirements 

In addition to Condition II.C.4.a above, the Permittee shall report 

emissions exceeding an emission limitation or standard as deviations in 

accordance with Section XII.B of Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b]

c. When no emission exceedances/deviations have occurred and the 

continuous emission monitoring system(s) have not been inoperative, 

repaired, or adjusted, such information shall be included in the quarterly 

report. [A.A.C. R18-2-306.A.5.b and 313.E.5]

d. The Permittee shall comply with all reporting requirements of 40 CFR 

Part 75 Subparts G. [A.A.C. R18-2-306.A.4 and 5] 

5. Performance Testing Requirements 

a. Opacity

 The Permittee shall perform an annual opacity observation of the stack of 

Steam Boiler Unit 1 in accordance with EPA Reference Method 9. 

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

b. Particulate Matter 

The Permittee shall conduct annual performance test during operation at 

the nominal rated capacity of the unit using Reference Method 5 listed in 

Appendices to 40 CFR Part 60 to determine compliance with the 

particulate matter emissions standard specified in Condition II.C.1.b from 

the stack of Steam Boiler Unit 1. [A.A.C. R18-2-311.A, 312.A, 703.B and 703.K] 
TV Renewal Permit No. 53399 Page 21 of 109 May 31, 2012 

APS-Cholla Generating Station 

6. Compliance Assurance Monitoring for Particulate Matter 

The Permittee shall conduct compliance assurance monitoring as required in 

Attachment “E” of this permit for Steam Boiler Unit 1. [40 CFR Part 64] 

7. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under A.A.C. R18-2-702.B.3, 702.C, 703, for 

the affected source subject to this Section. [A.A.C. R18-2-325 

D. Sulfur Dioxide 

1. Emission Limitations/Standards 

a. The Permittee shall not cause, allow, or permit emissions of more than 

1.0 pounds of sulfur dioxide maximum three hour average, per million 

Btu (430 nanograms per joule) heat input from the stack of Steam Boiler 

Unit 1. [A.A.C. R18-2-703.G.1] 

b. The Permittee shall achieve at least 80 percent sulfur dioxide removal 

efficiency from the Steam Boiler Unit 1 and associated control device on 

a 30 successive boiler operating day rolling average. [Installation Permit No. 1247, Attachment “B”, Condition II.B] 

 2. Air Pollution Control Requirements 

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

malfunction, to the extent practicable, operate and maintain Steam Boiler Unit 1 

and the tray tower absorber in a manner consistent with good air pollution 

control practice for minimizing sulfur dioxide emissions. The Permittee shall 

inspect and maintain the fabric filter control device in accordance with 

manufacturer specifications. [A.A.C. R18-2-306.A.2 and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

 

3. Monitoring and Recordkeeping Requirements 

Continuous Monitoring for SO2 and O2 /CO2 

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

emission monitoring systems (CEMS) for measuring sulfur dioxide 

emissions and diluent oxygen/carbon dioxide (O2 /CO2) at both the inlet 

and outlet of the sulfur dioxide control device. [A.A.C. R18-2-703.J, A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

b. The Permittee shall record SO2 and O2/CO2 CEMS data during all 

periods of operation of Steam Boiler Unit 1 including periods of startup, 

shutdown, malfunction or emergency conditions, except for continuous 

monitoring system breakdown, repairs, calibration checks, and zero and 

span adjustments. [A.A.C. R18-2-703.J] 

 

c. The continuous emission monitoring systems for SO2 and O2/CO2 shall 

meet the following requirements: [A.A.C. R18-2-313]
TV Renewal Permit No. 53399 Page 22 of 109 May 31, 2012 

APS-Cholla Generating Station 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality control program 

(2) Frequency of testing 

iii. Data Reduction 

The Permittee shall comply with the data reduction requirements 

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

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

d. Sulfur Dioxide Emissions Missing Data Supplemental Procedures 

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

The Permittee shall obtain the SO2 emission data for at least 18 hours in 

at least 22 out of 30 successive boiler operating days. If this minimum 

data requirement cannot be met with the continuous monitoring system 

in use, the Permittee shall supplement SO2 emission data with other 

monitoring systems approved by the Director or the following reference 

methods and procedures: 

i. Reference Method 6 shall be used to determine the SO2

concentration at the same location as the SO2 monitor. 

ii. The emission rate correction factor, integrated bag sampling and 

analysis procedure of Reference Method 3B shall be used to 

determine the O2 /CO2 concentration at the same location as the 

O2 /CO2 monitor. 

iii. The procedures in Reference Method 19 shall be used to 

compute each 1-hour average concentration in ng/J (pounds per 

million Btu). 
TV Renewal Permit No. 53399 Page 23 of 109 May 31, 2012 

APS-Cholla Generating Station 

iv. As alternatives, the reference methods and procedures described 

in 40 CFR 49Da(j) may be used.

e. The Permittee shall comply with all the recordkeeping requirements of 

40 CFR Part 75 Subparts G. [A.A.C. R18-2-306.A.4] 

4. Reporting Requirements 

a. Quarterly Reporting Requirements 

i. The Permittee shall submit to the Director a written report of all 

emission exceedances for each calendar quarter and the nature 

and cause of the exceedances, if known, postmarked by the 30th 

day following the end of each calendar quarter. The averaging 

period used for data reporting shall correspond to the averaging 

period specified in the emission standard. The required report 

shall include, as a minimum, the data stipulated in this 

subsection. [A.A.C. R18-2-313.E.1] 

ii. For gaseous measurements the summary shall consist of 

emission averages in the units of the applicable standard for 

each averaging period during which the applicable standard was 

exceeded. [A.A.C. R18-2-313.E.3] 

iii. For SO2 removal efficiency, the summary shall include the 30-

day rolling average of the removal efficiency for each day in the 

quarter. [Installation Permit No. 1247] 

iv. The date and time identifying each period during which the 

continuous emission monitoring system was inoperative, except 

for zero and span checks and the nature of system repair or 

adjustment shall be reported. The Director may require proof of 

continuous emission monitoring system performance whenever 

system repairs or adjustments have been made. 

 [A.A.C. R18-2-313.E.4] 

b. Emission Deviations Reporting Requirements 

In addition to Condition II.D.4.a above, the Permittee shall report 

emissions exceeding an emission limitation or standard as deviations in 

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

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

c. When no emission exceedances/deviations have occurred and the 

continuous emission monitoring system(s) have not been inoperative, 

repaired, or adjusted, such information shall be included in the quarterly 

report. [A.A.C. R18-2-306.A.5.b and 313.E.5]

d. The Permittee shall comply with all the reporting requirements of 40 

CFR Part 75 Subparts G. [A.A.C. R18-2-306.A.5] 

5. Performance Testing Requirements 

a. The Permittee use the applicable reference methods given in the 

Appendices to 40 CFR Part 60 to determine compliance with the standard 

of sulfur dioxide emissions from the stack of Steam Boiler Unit 1, as 
TV Renewal Permit No. 53399 Page 24 of 109 May 31, 2012 

APS-Cholla Generating Station 

specified in Condition II.D.1.a of this Attachment. The performance test 

using such reference methods shall be conducted annually and during 

operation at the nominal rated capacity of the unit. 

[A.A.C. R18-2-311.A, 312.A, 703.B and 703.K] 

 

b. To determine compliance with the 30 successive boiler operating day 

rolling average SO2 removal efficiency specified in Condition II.D.1.b of 

this Attachment, the Permittee shall calculate average daily removal 

efficiency using the 1-hour average CEMS data and Reference Method 

19. The Permittee shall accumulate the average daily removal 

efficiencies at the end of each boiler operating day for the last 30 

successive boiler operating days to calculate the 30-day rolling average 

removal efficiency and to determine compliance with the standard of 

80% removal efficiency. [A.A.C. R18-2-306.A.3.c] 

c. The Permittee shall obtain SO2 emission data for at least 18 hours in at 

least 22 out of 30 successive boiler operating days. If the Permittee has 

not obtained the required minimum quantity of data, compliance of 

Steam Boiler Unit 1 with the SO2 emission requirements under Condition 

II.D.1.b of this Attachment for the day on which the 30-day period ends 

shall be determined by following the applicable procedures in Section 7 

of EPA Reference Method 19. [A.A.C. R18-2-306.A.3.c] 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under A.A.C. R18-2-703.G.1 and Installation 

Permit #1247 for the affected source subject to this Section. [A.A.C. R18-2-325] 

 E. Nitrogen Oxides 

 

 1. Air Quality Control Requirements 

At all times including periods of startup, shutdown and malfunction, to the extent 

practicable, the Permittee shall operate and maintain Steam Boiler Unit 1 and 

associated low NOx burners in a manner consistent with good air pollution 

control practice for minimizing nitrogen oxides emissions. The Permittee shall 

inspect and maintain the fabric filter control device in accordance with 

manufacturer specifications. [A.A.C. R18-2-306.A.2 and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics] 

F. Carbon Monoxide

 1. Emission Limits/Standards 

a. At all times, excluding periods of startup and shutdown, the Permittee 

shall not cause to be discharged into the atmosphere from the stack of 

Steam Boiler Unit 1, any gases which contain carbon monoxide in excess 

of: 

i. 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]

ii. 0.75 lb per million Btu heat input derived from combustion of 

fuel, on an hourly basis. [A.A.C. R18-2-406.A.5] 
TV Renewal Permit No. 53399 Page 25 of 109 May 31, 2012 

APS-Cholla Generating Station 

b. During periods of startup and shutdown, the Permittee shall not cause to 

be discharged into the atmosphere from the stack of Steam Boiler Unit 1, 

any gases which contain carbon monoxide in excess of 250 pounds per 

hour. [A.A.C. R18-2-406.A.5] 

2. Air Quality Control Requirements [A.A.C. R18-2-406.A.4]

a. At all times, including periods of startup, shutdown and malfunction, to 

the extent practicable, the Permittee shall operate and maintain Steam 

Boiler Unit 1 and associated low NOx burners in a manner consistent 

with good combustion practices for minimizing carbon monoxide 

emissions. A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. For the purpose of this Section, the good combustion practices shall 

include, but is not limited to, the following components: 

i. Good air/fuel mixing in the combustion zone; 

ii. High temperatures and low oxygen levels in the primary 

combustion zone; 

iii. Overall excess oxygen levels high enough to complete 

combustion while maximizing boiler thermal efficiency; and 

iv. Sufficient residence time to complete combustion. 

c. Determination of whether the good combustion practices are being 

implemented for minimizing boiler carbon monoxide emissions will be 

based on information available to the Director which may include, but 

not limited to, monitoring results, review of operation and maintenance 

procedures and records, and inspection of the source. 

3. Monitoring, Recordkeeping and Reporting Requirements 

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

emission monitoring system (CEMS) at each affected steam boiler unit, 

and record the output of the system, for measuring carbon monoxide 

(CO) and diluent (O2/CO2) emissions from exhaust of the boiler’s stack. 

The output of the CEMS shall be expressed in pounds CO per million 

Btu heat input. 

[A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. The existing diluent (O2/CO2) continuous monitoring systems required 

under Sections III.E.3, IV.E.3 or V.E.3 of Attachment “B” of the permit 

may be used to satisfy the requirement for monitoring of diluent 

emissions. 

c. All continuous monitoring systems shall meet the following 

requirements: [A.A.C. R18-2-306.A.3.a and 406.A.4]

i. 40 CFR Part 75, Appendix A "Specification and Test 

Procedures" for installation of the NOx monitor shall be used for 

CO monitor by substituting NOx for CO. Due to normal 
TV Renewal Permit No. 53399 Page 26 of 109 May 31, 2012 

APS-Cholla Generating Station 

combustion variability, a dual range CO monitor shall be 

installed. The RATA specification shall be measured with 2 

decimal places in lb CO per million BTU. 

ii. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” for CO and O2/CO2 monitors 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

iii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality assurance/quality control program 

(2) Frequency of testing 

iv. 40 CFR Part 60 Appendix “F”, Quality Assurance Procedure for 

CO monitor for determining with pounds per hour emission rate 

under Condition XIV.A.2 of this Attachment. 

v. Data Reduction 

The Permittee shall comply with the data reduction requirements 

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

vi. Missing Data Substitution 

(1) The Permittee shall, in processing any CO emission data 

gaps throughout operation, comply with the appropriate 

provisions in 40 CFR Part 75, Subpart D, “Missing Data 

Substitution Procedures” and Appendix C, “Missing 

Data Estimation Procedures”. For the purpose of this 

Section, when monitor data availability reaches below 

80%, all CO emission data gaps shall be substituted 

using a CO emission rate not less than 0.75 lb per million 

Btu heat input derived from combustion of fuel. 

(2) The Permittee may elect to supplement CO emission data 

with the following USEPA reference methods and 

procedures: 

(a) Reference Method 10 shall be used to determine 

the CO concentration at the same location as the 

CO monitor. 

(b) The emission rate correction factor, integrated 

bag sampling and analysis procedure of 
TV Renewal Permit No. 53399 Page 27 of 109 May 31, 2012 

APS-Cholla Generating Station 

Reference Method 3B shall be used to determine 

the O2/CO2 concentration at the same location as 

the O2/CO2 monitor. 

(c) The procedures in Reference Method 19 shall be 

used to compute each 1-hour average 

concentration in ng/J (pounds per million Btu). 

(d) As Method 19 does not provide conversion 

factors for carbon monoxide, a conversion factor 

of 7.269×10-8 shall be used to convert parts per 

million (ppm) to pounds per standard cubic foot 

(lb/scf). 

vii. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

d. Except for system breakdowns, repairs, calibration checks, and zero and 

span adjustments, each continuous monitoring system prescribed in this 

Section shall complete a minimum of one cycle of operation (sampling, 

analyzing, and data recording) for each successive 15-minute period.

[A.A.C. R18-2-306.A.3.a and 406.A.4]

e. CO Emissions Compliance Determination 

 [A.A.C. R18-2-406.A.4 and 5]

i. The Permittee shall use CO emission data measured and 

recorded by the continuous monitoring systems prescribed in 

this Section to demonstrate compliance with the carbon 

monoxide emission standards set forth in Condition XIV.A of 

this Attachment. 

ii. Compliance with Condition II.F.1.a.i of this Attachment shall be 

based on the average emission rate for 30 successive calendar 

days. A new 30-day average carbon monoxide emission rate 

shall be determined at the end of each calendar day by 

calculating the arithmetic average of all hourly carbon monoxide 

emission rates for the past 30 successive calendar days, except 

for data obtained during periods of startup, shutdown, or 

malfunction. 

iii. The following shall be considered periods of excess emissions: 

(1) Any calendar day for which the 30-day rolling average 

CO emission rate, excluding periods of startup, 

shutdown, or malfunction, as determined by the 

applicable continuous monitoring systems in accordance 

with Condition II.F.3.e.ii above exceeds the 30-day 

average CO emission limit set forth in Condition 

II.F.1.a.i of this Attachment. 

(2) Any hour for which the hourly CO emission rate, 

excluding periods of startup, shutdown or malfunction, 

as measured by the applicable continuous monitoring 

systems of this Section exceeds the hourly CO emission 

limit set forth in Condition II.F.1.a.ii of this Attachment. 
TV Renewal Permit No. 53399 Page 28 of 109 May 31, 2012 

APS-Cholla Generating Station 

(3) Any periods of startup, shutdown or malfunction, for 

which the CO emissions rate for any unit exceeds the 

emission limit set forth in Condition II.F.1.b of this 

Attachment. 

iv. All excess emissions shall be reported in accordance with 

Section XII, Attachment “A” of the permit. [A.A.C. R18-2-306.A.5.b and 310.01]

f. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this part 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports, and records. 

[A.A.C. R18-2-306.A.4.a and 406.A.4] 

III. STEAM BOILER UNIT 2 

A. Applicability 

 This section applies to Unit 2 boiler as described in Attachment “C” of this permit. 

B. Fuel Limitation 

The Permittee shall burn only the following fuels in Steam Boiler Unit 2: 

1. Coal; 

2. No. 2 fuel oil for startup and stabilization. [Installation Permit No. 1037]

C. Operation Procedures 

1. Startup 

a. The Permittee shall place in service, the Venturi scrubbers and absorbers 

of the unit within one hour of startup of the boiler-induced draft fans and 

forced draft fans and before fires are in the boiler. 

b. Upon installation of the lime slurry Flue Gas Desulfurization (FGD) 

system on Unit 2, during startups the fabric filter shall be placed in 

service before startup of any boiler forced draft or induced draft fan. 

The fabric filter may be removed from service just prior to igniting oil 

fires (startup fuel) but must be returned to service before coal fires are 

placed in the boiler. The FGD system shall be placed in service after the 

fabric filter is placed in service, and before coal fires are in the boiler. 

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

 [Material Permit Condition identified by underline and italics]

2. Shutdown 

a. The Permittee shall keep the Venturi scrubbers and absorbers of the unit 

in service after fires in the boiler are out and shall not be taken out of 

service until just prior to the boiler forced draft fans and induced draft 

fans being turned off.
TV Renewal Permit No. 53399 Page 29 of 109 May 31, 2012 

APS-Cholla Generating Station 

b. Upon installation of the lime slurry Flue Gas Desulfurization (FGD) 

system on Unit 2, during shutdowns the fabric filter shall remain in 

service until after the boiler forced draft fans and induced draft fans have 

been turned off. The FGD system shall remain in service until coal fires 

in the boiler are out. [40 CFR 60.11(d), A.A.C. R18-2-331.A.3.a] 

 [Material Permit Condition identified by underline and italics] 

3. Malfunction 

a. Any malfunction of the Venturi scrubbers unit that exceeds four hours, 

and if fires are in the boiler, the Permittee shall reduce the unit’s load so 

that the Venturi scrubbers in service can properly process and treat the 

volume of flue gas being produced. If a malfunction makes it impossible 

to properly process and treat the volume of flue gas being produced, the 

unit shall be shut down. [40 CFR 60.11(d)] 

b. Any malfunction of the FGD unit that exceeds four hours, and if fires are 

in the boiler, the Permittee shall reduce the unit’s load so that the FGD in 

service can properly process and treat the volume of flue gas being 

produced. If a malfunction makes it impossible to properly process and 

treat the volume of flue gas being produced, the unit shall be shut down.

[40 CFR 60.11(d)] 

4. Emergency [PSD Permit No. M170843S1-98] 

During emergency conditions as defined in 40 CFR 60.41Da, Steam Boiler Unit 

2 with a malfunctioning flue gas desulfurization (FGD) system may be operated 

if sulfur dioxide emissions are minimized by: 

a. Operating all operable flue gas desulfurization system modules, and 

bringing back into operation any malfunctioned module as soon as 

repairs are completed; [40 CFR 60.48Da(d)(1), A.A.C. R18-2-331.A.3.a]

 [Material Permit Condition identified by underline and italics] 

b. Bypassing flue gases around only those flue gas desulfurization system 

modules that have been taken out of operation because they were 

incapable of any sulfur dioxide emission reduction or which would have 

suffered significant physical damage if they had remained in operation; 

and [40 CFR 60.48Da(d)(2), A.A.C. R18-2-331.A.3.a]

 [Material Permit Condition identified by underline and italics] 

c. Designing, constructing, and operating a spare FGD system module for 

Steam Boiler Unit 2, the Permittee shall demonstrate the capability of the 

spare FGD system in accordance with 40 CFR 60.48Da(d)(3). [40 CFR 60.48Da(d)(3), A.A.C. R18-2-331.A.3.a] 

 [Material Permit Condition identified by underline and italics] 

D. Particulate Matter & Opacity 

1. Emission Limits/Standards 

a. Opacity

The opacity of emissions from the stack of Steam Boiler Unit 2 shall not 

be greater than 20 percent at all times except for periods of startup, 
TV Renewal Permit No. 53399 Page 30 of 109 May 31, 2012 

APS-Cholla Generating Station 

shutdown, and malfunction as defined in Conditions I.A.1, 2 and 3 of this 

Attachment, and for one six-minute period per hour of not more than 27 

percent opacity. Opacity readings of portions of plumes which contain 

condensed, uncombined water vapor shall not be used for purposes of 

determining compliance with the opacity standard. [40 CFR 60.42(a)(2), 60.11(c) and 60.11(e)(1), A.A.C. R18-2-331.A.3.a]

 [Material Permit Condition identified by underline and italics]

b. Particulate Matter 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 2, any gases which contain particulate 

matter in excess of 43 nanogram per joule heat input (0.10 lb per million 

Btu) derived from fossil fuel. [40 CFR 60.42(a)(1)] 

2. Air Pollution Control Requirements 

a. Until the installation of fabric filters on Unit 2, the Permittee shall at all 

times, including periods of startup, shutdown, and malfunction and to the 

extent practicable, continue to operate and maintain Steam Boiler Unit 2 

and its mechanical dust collectors and Venturi scrubbers in a manner 

consistent with good air pollution control practice for minimizing 

particulate matter emissions. The Permittee shall inspect and maintain 

the dust collectors and scrubbers in accordance with manufacturer 

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

 [Material Permit Condition identified by underline and italics]

b. Upon the installation of the fabric filters on Unit 2, the Permittee shall at 

all times, including periods of startup, shutdown, and malfunction and to 

the extent practicable, continue to operate and maintain Steam Boiler 

Unit 2 and the fabric filter control device in a manner consistent with 

good air pollution control practice for minimizing particulate matter 

emissions. The Permittee shall inspect and maintain the fabric filter 

control device in accordance with manufacturer specifications. 

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

 [Material Permit Condition identified by underline and italics]

3. Monitoring, Recordkeeping & Reporting Requirements 

Continuous Monitoring for Opacity 

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

monitoring system (COMS) at the fabric filter outlet for measuring the 

opacity of emissions. [40 CFR 60.45(a), A.A.C. R18-2-331.A.3.c]

 [Material Permit Condition identified by underline and italics]

b. The COMS shall meet the following requirements: 

i. 40 CFR 60, Appendix B, Performance Specification 1, 

“Specification and Test Procedures for Opacity Continuous 

Emission Monitoring Systems in Stationary Sources” 

 [40 CFR 60.13]

(1) Apparatus 

(2) Installation Specifications 

(3) Design and Performance Specifications 
TV Renewal Permit No. 53399 Page 31 of 109 May 31, 2012 

APS-Cholla Generating Station 

(4) Design Specifications Verification Procedure 

(5) Performance Specifications Verification Procedure 

(6) Equations 

ii. Quality assurance requirements: 

(1) Calibration Checks 

The Permittee shall check the zero (or low-level value 

between 0 and 20% of span value) and span calibration 

drifts at least once daily in accordance with a written 

procedure. [40 CFR 60.13(d)(1)] 

(2) Zero and Span Drift Adjustments 

(a) The zero and span shall, as a minimum, be 

adjusted whenever the 24-hr zero drift or 24-hr 

span drift exceeds 4% opacity. [40 CFR 60.13(d)(1)] 

(b) The system shall allow for the amount of excess 

zero and span drift measured at the 24-hour 

interval checks to be recorded and quantified. 

 [40 CFR 60.13(d)(1)] 

(c) The optical surfaces exposed to the effluent 

gases shall be cleaned prior to performing the 

zero and span drift adjustments, except for 

systems using automatic zero adjustments. 

 [40 CFR 60.13(d)(1)] 

(d) For systems using automatic zero adjustments, 

the optical surfaces shall be cleaned when the 

cumulative automatic zero compensation 

exceeds 4% opacity. [40 CFR 60.13(d)(1)] 

(3) System Checks 

A method for producing a simulated zero opacity 

condition and an upscale (span) opacity condition using 

a certified neutral density filter or other related technique 

to produce a known obscuration of the light beam to 

provide a system check of the analyzer internal optical 

surfaces and all electronic circuitry including the lamp 

and photo detector assembly shall be used by the 

Permittee. [40 CFR 60.13(d)(2)]

(4) Minimum Frequency of Operation 

Except during periods of system breakdowns, repairs, 

calibration checks, and zero and span adjustments, the 

COMS shall be in continuous operation and shall 

complete a minimum of one cycle of sampling and 

analyzing for each successive 10-second period and one 
TV Renewal Permit No. 53399 Page 32 of 109 May 31, 2012 

APS-Cholla Generating Station 

cycle of data recording for each successive 6-minute 

period. [40 CFR 60.13(e)(1)]

(5) Data Reduction Procedures [40 CFR 60.13(h)] 

(a) The Permittee shall reduce all data from the 

COMS to 6-minute averages. Six-minute 

opacity averages shall be calculated from 36 or 

more data points equally spaced over each 6-

minute period. 

(b) 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 Condition. An arithmetic or integrated 

average of all data may be used. 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements specified in 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 2 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly Excess Emissions and Monitoring System Performance 

Reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c), & (d), 60.45(g), 60.51Da(j) and 60.51Da(k)]
TV Renewal Permit No. 53399 Page 33 of 109 May 31, 2012 

APS-Cholla Generating Station 

ii. The summary report form submission required in the preceding 

Condition III.D.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

e. Definitions 

Opacity excess emissions are defined as any six-minute period during 

which the average opacity of emissions from Steam Boiler Unit 2 stack 

exceeds 20 percent opacity as measured by a continuous opacity monitor, 

except that one six-minute average per hour of up to 27 percent opacity 

need not be reported. [40 CFR 60.45(g)(1)] 

f. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition III.D.4.d

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b]

5. Performance Testing Requirements 

a. Opacity

 The Permittee shall perform an annual opacity observation of the stack of 

Steam Boiler Unit 2 in accordance with EPA Reference Method 9. 

 [40 CFR 60.8(a) and 46(b)(3)] 

b. Particulate Matter 

 

 The Permittee shall perform annual performance tests for particulate 

matter emissions from the stack of Steam Boiler Unit 2, using the 

following reference methods and procedures: [40 CFR 60.8(a)] 
TV Renewal Permit No. 53399 Page 34 of 109 May 31, 2012 

APS-Cholla Generating Station 

i. Reference Method 

EPA Reference Method 5 or 5B hall be used to determine the 

particulate matter concentration (C) at the stack of Steam Boiler 

Unit 2. [40 CFR 60.46(b)(2)] 

ii. Emission Rate 

For the purpose of compliance determination, the emission rate 

(E) of PM shall be computed for each run using the following 

equation: [40 CFR 60.46(d)(1)] 

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

 Or 

 E = C Fc (100/%CO2) 

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

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

 %O2 = oxygen concentration, percent dry basis. 

 %CO2 = carbon monoxide concentration, percent dry basis. 

 Fd = factor as determined from Method 19 

 Fc = factor as determined in appropriate sections of Method 19. 

iii. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

6. Compliance Assurance Monitoring for Particulate Matter

The Permittee shall conduct the compliance assurance monitoring required in 

Attachment “E” of this permit for Steam Boiler Unit 2. [40 CFR Part 64]

7. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance of the 

affected sources subject to this Section with the applicable requirements 

prescribed under 40 CFR 60.42, 40 CFR 60.42, 40 CFR 60.45, 40 CFR 60.46, 40 

CFR 60.46, 40 CFR 60.46, and 40 CFR Part 64. [A.A.C. R18-2-325] 

E. Sulfur Dioxide Standard 

1. Emission Limitations/Standards

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

Steam Boiler Unit 2 any gases which contain sulfur dioxide in excess of 

0.8 pounds per million Btu heat input; and 

 [PSD Permit No. M170843S1-98, Attachment “B”, Condition XII.B.1] 
TV Renewal Permit No. 53399 Page 35 of 109 May 31, 2012 

APS-Cholla Generating Station 

b. The Permittee shall not cause to be discharged into the atmosphere from 

Steam Boiler Unit 2, any gases which contain sulfur dioxide in excess of 

10 percent of the potential combustion concentration (90 percent 

reduction). 

 [PSD Permit No. M170843S1-98, Attachment “B”, Condition XII.B.1] 

c. The sulfur dioxide emission standards required under Conditions 

III.E.1.a and b above shall apply at all times except during periods of 

startup, shutdown, or when emergency conditions, as defined in 40 CFR 

60.41Da, exist and emergency procedures under Condition III.C.4 of this 

Attachment are implemented. [PSD Permit No. M170843S1-98] 

2. Air Pollution Control Requirements 

a.. Until the installation of lime slurry Flue Gas Desulfurization (FGD), the

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

malfunction and to the extent practicable, continue to operate and 

maintain Steam Boiler Unit 2 and its lime thiosulfate Venturi flooded disc 

scrubbers (Venturi scrubbers) and absorbers in a manner consistent with 

good air pollution control practice for minimizing sulfur dioxide 

emissions. The Permittee shall inspect and maintain the scrubbers and 

absorbers in accordance with manufacturer specifications. 

 [40 CFR 60.11(d) and PSD Permit No. M170843S1-98, 

 Attachment “B”, Condition XVI and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics] 

b. Upon the installation of lime slurry Flue Gas Desulfurization (FGD), 

following, the Permittee shall at all times, including periods of startup, 

shutdown, and malfunction and to the extent practicable, continue to 

operate and maintain Steam Boiler Unit 2 and the lime slurry FGD in a 

manner consistent with good air pollution control practice for 

minimizing sulfur dioxide emissions. The Permittee shall inspect and 

maintain the FGD control device in accordance with manufacturer 

specifications. [40 CFR 60.11(d) and PSD Permit No. M170843S1-98, 

 Attachment “B”, Condition XVI and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics] 

 3. Monitoring Requirements 

Continuous Monitoring for SO2 and O2 /CO2

 [PSD Permit No. M170843S1-98, Attachment “B”, Condition XV.A]

a. The Permittee shall calibrate, maintain, and operate a CEMS, and record 

the output of the system, for measuring sulfur dioxide emissions. The 

sulfur dioxide emissions shall be monitored at both the inlet and outlet of 

the sulfur dioxide control device. [Material Permit Condition identified by underline and italics]

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

monitoring system, and record the output of the system, for measuring 

the O2 /CO2 content of the flue gases at each location where SO2

emissions are monitored. [40 CFR 60.49Da(d), A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

c. The Permittee shall operate the SO2 and O2 /CO2 continuous monitoring 

systems and record data during all periods of operation of Steam Boiler 

Unit 2 including periods of startup, shutdown, malfunction or emergency 
TV Renewal Permit No. 53399 Page 36 of 109 May 31, 2012 

APS-Cholla Generating Station 

conditions, except for continuous monitoring system breakdown, repairs, 

calibration checks, and zero and span adjustments. [40 CFR 60.49Da(e)] 

d. The Permittee shall obtain the SO2 emission data for at least 18 hours in 

at least 22 out of 30 successive boiler operating days. 

 [40 CFR 60.49Da(f)] 

e. The continuous emission monitoring systems for SO2, and O2 /CO2 shall 

meet the following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” [40 CFR 60.13] 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” [40 CFR 60.13]

(1) Quality control program 

(2) Frequency of testing 

iii. Data Reduction [40 CFR 60.13(h)] 

The Permittee shall comply with the data reduction requirements 

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

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

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

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

f. Sulfur Dioxide Emissions Missing Data Supplemental Procedures 

[40 CFR 60.49Da(f), (h) and (j) and PSD Permit No. 

M170843S1-98, Attachment “B”, Condition XV.A] 

If the minimum data requirement specified in Condition III.E.3.d above 

cannot be met with the continuous monitoring system in use, the 

Permittee shall supplement SO2 emission data with other monitoring 

systems approved by the Director or the following reference methods and 

procedures: 
TV Renewal Permit No. 53399 Page 37 of 109 May 31, 2012 

APS-Cholla Generating Station 

i. Reference Method 6 shall be used to determine the SO2

concentration at the same location as the SO2 monitor. 

ii. The emission rate correction factor, integrated bag sampling and 

analysis procedure of Reference Method 3B shall be used to 

determine the O2/CO2 concentration at the same location as the 

O2/CO2 monitor. 

iii. The procedures in Reference Method 19 shall be used to 

compute each 1-hour average concentration in ng/J (pounds per 

million Btu). 

iv. As alternatives, the reference methods and procedures described 

in 40 CFR 49Da(j) may be used. 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements specified in 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 2 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)] 

ii. The summary report form submission required in the preceding 

Condition III.E.4.d shall be in the format specified in 40 CFR 
TV Renewal Permit No. 53399 Page 38 of 109 May 31, 2012 

APS-Cholla Generating Station 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

e. Excess Emissions Definition 

Unless otherwise specified, SO2 excess emissions are defined as any 30 

successive boiler operating days for which, except for data obtained 

during startup, shutdown, or emergency conditions, the arithmetic 

average of all hourly emission rates for sulfur dioxide exceeds the 

applicable standard of 0.8 pounds per million Btu heat input, or the 

percentage sulfur dioxide reduction falls below the applicable standard of 

90 percent, as required in Condition III.E.1 of this attachment. The 

percentage sulfur dioxide reduction is determined based on the average 

inlet and average outlet SO2 emission rates for the 30 successive boiler 

operating days. [40 CFR 60.48Da(e), (g) and 

 PSD Permit No. M170843S1-98, Attachment “B”, Condition XII.A] 

f. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition III.E.4.d

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b]

g. Subpart Da Reporting Requirements for Sulfur Dioxide 

[PSD Permit No. M170843S1-98, Attachment "B", Condition XV.B.6] 

The Permittee shall include in the quarterly reports required under 

Condition III.E.4.d above, the following additional information in regard 

to sulfur dioxide: 

i. For sulfur dioxide, the following information shall be reported to 

the Director for each 24-hour period: [40 CFR 60.51Da(b)]
TV Renewal Permit No. 53399 Page 39 of 109 May 31, 2012 

APS-Cholla Generating Station 

(1) Calendar date; 

(2) Average sulfur dioxide 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 non-compliance with the emission standards; and 

description of corrective actions taken. 

(3) Percent reduction of the potential combustion 

concentration of sulfur dioxide for each 30 successive 

boiler operating days, ending with the last 30-day period 

in the quarter; reasons for non-compliance with the 

emission standards; and description of corrective actions 

taken. 

(4) Identification of the boiler operating days for which 

pollutant or diluents’ 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. 

(5) Identification of the time when emissions data have been 

excluded from the calculation of average emission rates 

because of startup, shutdown, emergency conditions, or 

other reasons, and justification for excluding data for 

reasons other than startup, shutdown, or emergency 

conditions. 

(6) Identification of “F” factor used for calculations, method 

of determination, and type of fuel combusted. 

(7) Identification of times when hourly averages have been 

obtained based on manual sampling methods. 

(8) Identification of the times when the pollutant 

concentration exceeded full span of the continuous 

monitoring system. 

(9) Description of any modifications to the continuous 

monitoring system which could affect the ability of the 

continuous monitoring system to comply with 

Performance Specification 2 or 3. 

ii. For the purpose of SO2 emission reporting, minimum quantity of 

SO2 emission data requires that the available data from CEMS 

for each boiler operating day be at least 18 hours in at least 22 

out of 30 successive boiler operating days. If the minimum 

quantity of emissions data is not obtained for any 30 successive 

boiler operating days, the following information shall be 

reported to the Director for that 30-day period: 

[40 CFR 60.49Da(f) and 51Da(c)] 

(1) The number of hourly averages available for the outlet 

emission rates (no) and the inlet emission rates (ni) as 

applicable. 
TV Renewal Permit No. 53399 Page 40 of 109 May 31, 2012 

APS-Cholla Generating Station 

(2) The standard deviation of hourly averages for the outlet 

emission rates (so) and inlet emission rates (si) as 

applicable. 

(3) 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. 

(4) The applicable potential combustion concentration. 

(5) The ratio of the upper confidence limit for the mean 

outlet emission rate (Eo*) and the allowable emission 

rate (Estd) as applicable. 

iii. If the sulfur dioxide standards under Condition III.E.1.a and b of 

this attachment are exceeded during emergency conditions 

because of control system malfunction, the Permittee shall 

submit a signed statement: [40 CFR 60.51Da(d)]

(1) Indicating if emergency conditions existed and 

requirements under Condition III.C.4 (Emergency 

Procedures) of this Attachment were met during each 

period, and 

(2) Listing the following information: 

(a) Time periods the emergency condition existed; 

(b) Electrical output and demand on the owner or 

operator's electric utility system and the affected 

facility; 

(c) Amount of power purchased from 

interconnected neighboring utility companies 

during the emergency period; 

(d) Percent reduction in emissions achieved; 

(e) Atmospheric emission rate (ng/J) of the 

pollutant discharged; and 

(f) Actions taken to correct control system 

malfunction. 

iv. If fuel pretreatment credit toward the sulfur dioxide emission 

standard is claimed, the Permittee shall submit a signed 

statement: [40 CFR 60.51Da(e)] 

(1) Indicating what percentage cleaning credit was taken for 

the calendar quarter, and whether the credit was 

determined in accordance with the provisions of III.E.5 

of this attachment and Method 19 (appendix A); and 
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APS-Cholla Generating Station 

(2) 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. 

v. For any periods for which sulfur dioxide 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 affected facility during 

periods of data unavailability are to be compared with operation 

of the control system and affected facility before and following 

the period of data unavailability. [40 CFR 60.51Da(f)] 

vi. The Permittee shall submit a signed statement indicating 

whether: [40 CFR 60.51Da(h)] 

(1) The required sulfur dioxide continuous monitoring 

system calibration, span, and drift checks or other 

periodic audits have or have not been performed as 

specified. 

(2) The data used to show compliance was or was not 

obtained in accordance with approved methods and 

procedures of this section and is representative of plant 

performance. 

(3) The minimum data requirements have or have not been 

met; or, the minimum data requirements have not been 

met for errors that were unavoidable. 

(4) Compliance with the standards has or has not been 

achieved during the reporting period. 

5. Compliance Demonstration Requirements 

Compliance determination procedures and methods 

a. The Permittee shall determine compliance with the SO2 standards 

specified in Conditions III.E.1.a and b of this Attachment as follows: 

i. The percent of potential SO2 emissions (%Ps) to the atmosphere 

shall be computed using the following equation: 

 [40 CFR 60.50Da(c)(1)] 

%Ps=[(100 - %Rf) (100 - %Rg)]/100 

where: 

%Ps=percent of potential SO2 emissions, percent 

%Rf=percent reduction from fuel pretreatment, percent 

%Rg=percent reduction by SO2 control system, percent 
TV Renewal Permit No. 53399 Page 42 of 109 May 31, 2012 

APS-Cholla Generating Station 

ii. The procedures in EPA Reference Method 19 may be used to 

determine percent reduction (%Rf) of sulfur by such processes as 

fuel pretreatment (physical coal cleaning, hydro desulphurization 

of fuel oil, etc.), coal pulverizers, and bottom and fly ash 

interactions. This determination is optional. [40 CFR 60.50Da(c)(2)] 

iii. The procedures in EPA Reference Method 19 shall be used to 

determine the percent SO2 reduction (%Rg) of any SO2 control 

system. [40 CFR 60.50Da(c)(3)] 

iv. The appropriate procedures in EPA Reference Method 19 shall

be used to determine the emission rate. [40 CFR 60.50Da(c)(4)] 

v. The continuous monitoring system required in Condition III.E.3. 

of this Attachment shall be used to determine the concentrations 

of SO2 and O2/CO2. [40 CFR 60.50Da(c)(5)] 

b. Compliance with the sulfur dioxide emission limitations and percentage 

reduction requirements under Conditions III.E.1.a and b of this 

Attachment shall be based on the average emission rate for 30 successive 

boiler operating days. A separate performance test shall be completed at 

the end of each boiler operating day, and a new 30 day average emission 

rate for sulfur dioxide and a new percent reduction for sulfur dioxide 

shall be calculated to show compliance with the standards. [40 CFR 60.48Da(e)] 

c. Compliance shall be determined by calculating the arithmetic average of 

all hourly emission rates for SO2 for the 30 successive boiler operating 

days, except for data obtained during startup, shutdown, or the 

emergency conditions defined in 40 CFR 60.41a. Compliance with the 

percentage reduction requirement for SO2 shall be determined based on 

the average inlet and average outlet SO2 emission rates for the 30 

successive boiler operating days. [40 CFR 60.48Da(g)] 

d. The Permittee shall obtain SO2 emission data for at least 18 hours in at 

least 22 out of 30 successive boiler operating days. If the Permittee has 

not obtained the minimum quantity, compliance of Steam Boiler Unit 2 

with the SO2 emission requirements under Conditions III.E.1.a and b of 

this attachment for the day on which the 30 day period ends may be 

determined by the Director by following the applicable procedures in 

section 7 of EPA Reference Method 19. [40 CFR 60.48Da(h)] 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance of the 

affected sources subject to this Section with the applicable requirements 

prescribed under PSD Permit No.M170843S1-98 for SO2. [A.A.C. R18-2-325] 

F. Nitrogen Oxide Standard 

1. Emission Limitations/Standards

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

the stack of Steam Boiler Unit 2 any gases which contain nitrogen 

oxides, expressed as NO2 in excess of 300 nanogram per joule heat input 

(0.70 lb per million Btu) derived from solid fossil fuel. 

 [40 CFR 60.44(a) and 44(a)(3)] 

b. Combination Fuels 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 2, when different fossil fuels are burned 

simultaneously in any combination, any gases which contain nitrogen 

oxides in excess of the applicable standard (in ng/J) derived using the 

following proration formula: [40 CFR 60.44(b)] 

zyxw

z(300) y(130) x(86) w(260)

NOx PS



   

Where: 

PSNOx = prorated standard for nitrogen oxides when burning different 

fuels simultaneously, in nanograms per joule heat input derived 

from all fossil fuels fired or from all fossil fuels and wood 

residue fired; 

w = percentage of total heat input derived from lignite; 

x = percentage of total heat input derived from gaseous fossil fuel; 

y = percentage of total heat input derived from liquid fossil fuel; 

and 

z = percentage of total heat input derived from solid fossil fuel 

(except lignite). 

 2. Air Quality Control Requirements 

At all times including periods of startup, shutdown and malfunction, to the extent 

practicable, the Permittee shall operate and maintain Steam Boiler Unit 2 and 

associated low NOx burners in a manner consistent with good air pollution 

control practice for minimizing nitrogen oxides emissions. The Permittee shall 

inspect and maintain the low-NOx burners in accordance with manufacturer 

specifications. [A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

3. Monitoring Requirements 

a. The Permittee shall calibrate, maintain, and operate a CEMS for 

measuring the nitrogen oxides emissions.

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

[Material Permit Condition identified by underline and italics]

b. The continuous emission monitoring systems for NOx, shall meet the 

following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” [40 CFR 60.13] 

(1) Installation and measurement location 

TV Renewal Permit No. 53399 Page 43 of 109 May 31, 2012 

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TV Renewal Permit No. 53399 Page 44 of 109 May 31, 2012 

APS-Cholla Generating Station 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality control program 

(2) Frequency of testing [40 CFR 60.13] 

iii. Data Reduction 

The Permittee shall comply with the data reduction requirements 

of 40 CFR Part 75.10(d)(1). [40 CFR 60.13(h)]

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. [40 CFR 60.45(a), A.A.C. R18-2-306.A.3.a] 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements specified in 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 2 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 
TV Renewal Permit No. 53399 Page 45 of 109 May 31, 2012 

APS-Cholla Generating Station 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)]

ii. The summary report form submission required in the preceding 

Condition III.F.3.b.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

e. Excess Emissions Definitions 

 NOx excess emissions for Steam Boiler Unit 2 are defined as any threehour period during which the average NOx emissions (arithmetic average 

of three contiguous one-hour periods), as measured by a continuous 

emissions monitoring system, exceed the applicable standards specified 

in Condition III.F.1 of this Attachment. [40 CFR 60.45(g)(3)] 

f. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition III.F.4.d

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b]

5. Performance Testing Requirements 

The Permittee shall perform annual performance tests for nitrogen oxides 
TV Renewal Permit No. 53399 Page 46 of 109 May 31, 2012 

APS-Cholla Generating Station 

emissions from the stack of Steam Boiler Unit 2, using the following reference 

methods and procedures: [40 CFR 60.8(a)] 

a. Reference Method 

EPA Reference Method 7 shall be used to determine the nitrogen oxides 

concentration (C) at the stack of Steam Boiler Unit 2. [40 CFR 60.46(b)(5)] 

b. Emission Rate 

For the purpose of compliance determination, the emission rate (E) of 

PM or NOx shall be computed for each run using the following equation: [40 CFR 60.46(d)(1)] 

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

 Or 

E = C Fc (100/%CO2) 

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

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

%O2 = oxygen concentration, percent dry basis. 

%CO2 = carbon monoxide concentration, percent dry basis. 

Fd = factor as determined from Method 19 

Fc = factor as determined in appropriate sections of Method 19. 

c. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance of the 

affected source subject to this Section with the applicable requirements 

prescribed under 40 CFR 60.44, 40 CFR 60.44, 40 CFR 60.44, and 40 CFR 

60.45. [A.A.C. R18-2-325] 

G. Carbon Monoxide 

1. Emission Limitations/Standards

a. At all times, excluding periods of startup and shutdown, the Permittee 

shall not cause to be discharged into the atmosphere from the stack of 

Steam Boiler Unit 2, any gases which contain carbon monoxide in excess 

of: 

i 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] 

ii. 0.75 lb per million Btu heat input derived from combustion of 

fuel, on an hourly basis. [A.A.C. R18-2-406.A.5] 

b. During periods of startup and shutdown, the Permittee shall not cause to 

be discharged into the atmosphere from the stack of Steam Boiler Unit 2, 
TV Renewal Permit No. 53399 Page 47 of 109 May 31, 2012 

APS-Cholla Generating Station 

any gases which contain carbon monoxide in excess of 350 pounds per 

hour. [A.A.C. R18-2-406.A.5] 

2. Air Quality Control Requirements [A.A.C. R18-2-406.A.4]

a. At all times, including periods of startup, shutdown and malfunction, to 

the extent practicable, the Permittee shall operate and maintain Steam 

Boiler Unit 2 and associated low NOx burners in a manner consistent 

with good combustion practices for minimizing carbon monoxide 

emissions. A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. For the purpose of this Section, the good combustion practices shall 

include, but is not limited to, the following components: 

i. Good air/fuel mixing in the combustion zone; 

ii. High temperatures and low oxygen levels in the primary 

combustion zone; 

iii. Overall excess oxygen levels high enough to complete 

combustion while maximizing boiler thermal efficiency; and 

iv. Sufficient residence time to complete combustion. 

c. Determination of whether the good combustion practices are being 

implemented for minimizing boiler carbon monoxide emissions will be 

based on information available to the Director which may include, but 

not limited to, monitoring results, review of operation and maintenance 

procedures and records, and inspection of the source. 

3. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall install, calibrate, maintain, and operate CEMS at 

each affected steam boiler unit, and record the output of the system, for 

measuring carbon monoxide (CO) and diluents (O2/CO2) emissions from 

exhaust of the boiler’s stack. The output of the CEMS shall be expressed 

in pounds CO per million Btu heat input. 

[A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. The existing diluents (O2/CO2) continuous monitoring systems required 

under Sections III.E of Attachment “B” of the permit may be used to 

satisfy the requirement for monitoring of diluents emissions. 

c. All continuous monitoring systems shall meet the following 

requirements: [A.A.C. R18-2-306.A.3.a and 406.A.4]

i. 40 CFR Part 75, Appendix A "Specification and Test 

Procedures" for installation of the NOx monitor shall be used for 

CO monitor by substituting NOx for CO. Due to normal 

combustion variability, a dual range CO monitor shall be 

installed. The RATA specification shall be measured with 2 

decimal places in lb CO per million BTU. 

ii. 40 CFR Part 75, Appendix A, “Specification and Test 
TV Renewal Permit No. 53399 Page 48 of 109 May 31, 2012 

APS-Cholla Generating Station 

Procedures” for CO and O2/CO2 monitors 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

iii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality assurance/quality control program 

(2) Frequency of testing 

iv. 40 CFR Part 60 Appendix “F”, Quality Assurance Procedure for 

CO monitor for determining with pounds per hour emission rate 

under Condition III.G.1.b of this Attachment. 

 v. Data Reduction 

The Permittee shall comply with the data reduction requirements 

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

 vi. Missing Data Substitution 

(1) The Permittee shall, in processing any CO emission data 

gaps throughout operation, comply with the appropriate 

provisions in 40 CFR Part 75, Subpart D, “Missing Data 

Substitution Procedures” and Appendix C, “Missing 

Data Estimation Procedures”. For the purpose of this 

Section, when monitor data availability reaches below 

80%, all CO emission data gaps shall be substituted 

using a CO emission rate not less than 0.75 lb per million 

Btu heat input derived from combustion of fuel. 

(2) The Permittee may elect to supplement CO emission data 

with the following USEPA reference methods and 

procedures: 

(a) Reference Method 10 shall be used to determine 

the CO concentration at the same location as the 

CO monitor. 

(b) The emission rate correction factor, integrated 

bag sampling and analysis procedure of 

Reference Method 3B shall be used to determine 

the O2/CO2 concentration at the same location as 

the O2/CO2 monitor. 

(c) The procedures in Reference Method 19 shall be 

used to compute each 1-hour average 
TV Renewal Permit No. 53399 Page 49 of 109 May 31, 2012 

APS-Cholla Generating Station 

concentration in ng/J (pounds per million Btu). 

(d) As Method 19 does not provide conversion 

factors for carbon monoxide, a conversion factor 

of 7.269×10-8 shall be used to convert parts per 

million (ppm) to pounds per standard cubic foot 

(lb/scf). 

vii. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

d. Except for system breakdowns, repairs, calibration checks, and zero and 

span adjustments, each continuous monitoring system prescribed in this 

Section shall complete a minimum of one cycle of operation (sampling, 

analyzing, and data recording) for each successive 15-minute period.

[A.A.C. R18-2-306.A.3.a and 406.A.4] 

e. CO Emissions Compliance Determination [A.A.C. R18-2-406.A.4 and 5]

i. The Permittee shall use CO emission data measured and 

recorded by the continuous monitoring systems prescribed in 

this Section to demonstrate compliance with the carbon 

monoxide emission standards set forth in Condition III.G.1 of 

this Attachment. 

ii. Compliance with Condition III.G.1.a.i of this Attachment shall 

be based on the average emission rate for 30 successive calendar 

days. A new 30-day average carbon monoxide emission rate 

shall be determined at the end of each calendar day by 

calculating the arithmetic average of all hourly carbon monoxide 

emission rates for the past 30 successive calendar days, except 

for data obtained during periods of startup, shutdown, or 

malfunction. 

iii. The following shall be considered periods of excess emissions: 

(1) Any calendar day for which the 30-day rolling average 

CO emission rate, excluding periods of startup, 

shutdown, or malfunction, as determined by the 

applicable continuous monitoring systems in accordance 

with Condition III.G.3.e.ii above exceeds the 30-day 

average CO emission limit set forth in Condition 

III.G.1.a.i of this Attachment. 

(2) Any hour for which the hourly CO emission rate, 

excluding periods of startup, shutdown or malfunction, 

as measured by the applicable continuous monitoring 

systems of this Section exceeds the hourly CO emission 

limit set forth in Condition III.G.1.a.ii of this 

Attachment. 

(3) Any periods of startup, shutdown or malfunction, for 

which the CO emissions rate for any unit exceeds the 
TV Renewal Permit No. 53399 Page 50 of 109 May 31, 2012 

APS-Cholla Generating Station 

emission limit set forth in Condition III.G.1.b of this 

Attachment. 

iv. All excess emissions shall be reported in accordance with 

Section XII, Attachment “A” of the permit. [A.A.C. R18-2-306.A.5.b and 310.01]

f. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this part 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports, and records. 

[A.A.C. R18-2-306.A.4.a and 406.A.4] 

IV. STEAM BOILER UNIT 3 

A. Applicability 

 This section applies to Unit 3 boiler as described in Attachment “C” of this permit. 

B. Fuel Limitation [Installation Permit No. 1037] 

 

The Permittee shall burn only the following fuels in Steam Boiler Unit 3: 

1. Coal. 

2. No. 2 fuel oil for startup and stabilization. 

 

C. Operation Procedures

1. Startup 

During startups of Steam Boiler Unit 3, the fabric filter shall be placed in 

service before startup of any boiler forced draft or induced draft fan. The fabric 

filter may be removed from service just prior to igniting oil fires (startup fuel) 

but must be returned to service before coal fires are placed in the boiler. The 

FGD system shall be placed in service after the fabric filter is placed in service, 

and before coal fires are in the boiler. 

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

 [Material Permit Condition identified by underline and italics]

b. Shutdown 

During shutdowns of Steam Boiler Unit 3 the fabric filter shall remain in service 

until after the boiler forced draft fans and induced draft fans have been turned 

off. The FGD system shall remain in service until coal fires in the boiler are out. [40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e]

 [Material Permit Condition identified by underline and italics]

c. Malfunction 

 For Steam Boiler Unit 3 with any malfunction of its fabric filter that exceeds 

four hours, if fires are in the boiler, the Permittee shall reduce the unit’s load so 

that the fabric filter compartments in service can properly process and treat the 
TV Renewal Permit No. 53399 Page 51 of 109 May 31, 2012 

APS-Cholla Generating Station 

volume of flue gas being produced. If a malfunction makes it impossible to 

properly process and treat the volume of flue gas being produced, the unit shall 

be shut down. [40 CFR 60.11(d)]

D. Particulate Matter & Opacity

1. Emission Limits/Standards 

a. Opacity

The opacity of emissions from the stack of Steam Boiler Unit 3 shall not 

be greater than 20 percent at all times except for periods of startup, 

shutdown, and malfunction as defined in Conditions I.A.1, 2 and 3 of this

Attachment, and for one six-minute period per hour of not more than 27 

percent opacity. Opacity readings of portions of plumes which contain 

condensed, uncombined water vapor shall not be used for purposes of 

determining compliance with the opacity standard. [40 CFR 60.42(a)(2), 60.11(c), 60.11(e)(1) and A.A.C. R18-2-331.A.3.a] 

 [Material Permit Condition identified by underline and italics]

b. Particulate Matter 

 The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 3, any gases which contain particulate 

matter in excess of 43 nanogram per joule heat input (0.10 lb per million 

Btu) derived from fossil fuel. [40 CFR 60.42(a)(1)] 

2. Air Pollution Control Requirements

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

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

Unit 3 and the fabric filter control device in a manner consistent with good air 

pollution control practice for minimizing particulate matter emissions. The 

Permittee shall inspect and maintain the fabric filter control device in accordance 

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

 [Material Permit Condition identified by underline and italics] 

3. Continuous Monitoring 

a. The Permittee shall calibrate, maintain, and operate COMS at the fabric 

filter outlet for measuring the opacity of emissions. 

 [40 CFR 60.45(a), A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

b. The continuous opacity monitoring system shall meet the following 

requirements: 

i. 40 CFR 60, Appendix B, Performance Specification 1, 

“Specification and Test Procedures for Opacity Continuous 

Emission Monitoring Systems in Stationary Sources” 

 [40 CFR 60.13] 

(1) Apparatus 

(2) Installation Specifications 

(3) Design and Performance Specifications 

(4) Design Specifications Verification Procedure 
TV Renewal Permit No. 53399 Page 52 of 109 May 31, 2012 

APS-Cholla Generating Station 

(5) Performance Specifications Verification Procedure 

(6) Equations 

ii. Quality assurance requirements: 

(1) Calibration Checks 

The Permittee shall check the zero (or low-level value 

between 0 and 20% of span value) and span calibration 

drifts at least once daily in accordance with a written 

procedure. [40 CFR 60.13(d)(1)] 

(2) Zero and Span Drift Adjustments 

(a) The zero and span shall, as a minimum, be 

adjusted whenever the 24-hr zero drift or 24-hr 

span drift exceeds 4% opacity. [40 CFR 60.13(d)(1)] 

(b) The system shall allow for the amount of excess 

zero and span drift measured at the 24-hour 

interval checks to be recorded and quantified. 

 [40 CFR 60.13(d)(1)] 

(c) The optical surfaces exposed to the effluent 

gases shall be cleaned prior to performing the 

zero and span drift adjustments, except for 

systems using automatic zero adjustments. 

 [40 CFR 60.13(d)(1)] 

(d) For systems using automatic zero adjustments, 

the optical surfaces shall be cleaned when the 

cumulative automatic zero compensation 

exceeds 4% opacity. [40 CFR 60.13(d)(1)] 

(3) System Checks 

A method for producing a simulated zero opacity 

condition and an upscale (span) opacity condition using 

a certified neutral density filter or other related technique 

to produce a known obscuration of the light beam to 

provide a system check of the analyzer internal optical 

surfaces and all electronic circuitry including the lamp 

and photo detector assembly shall be used by the 

Permittee. [40 CFR 60.13(d)(2)] 

(4) Minimum Frequency of Operation 

Except during periods of system breakdowns, repairs, 

calibration checks, and zero and span adjustments, the 

COMS shall be in continuous operation and shall 

complete a minimum of one cycle of sampling and 

analyzing for each successive 10-second period and one 

cycle of data recording for each successive 6-minute 

period. [40 CFR 60.13(e)(1)] 
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APS-Cholla Generating Station 

(5) Data Reduction Procedures [40 CFR 60.13(h)] 

(a) The Permittee shall reduce all data from the 

COMS to 6-minute averages. Six-minute 

opacity averages shall be calculated from 36 or 

more data points equally spaced over each 6-

minute period. 

(b) 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 Condition. An arithmetic or integrated 

average of all data may be used. 

4. Recordkeeping and Reporting Requirements

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 3 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)]

ii. The summary report form submission required in the preceding 

Condition IV.D.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 
TV Renewal Permit No. 53399 Page 54 of 109 May 31, 2012 

APS-Cholla Generating Station 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

iii. Definitions 

Periods of excess emissions and monitoring systems (MS) 

downtime that shall be reported are defined as follows: 

Opacity excess emissions are defined as any six-minute period 

during which the average opacity of emissions from Steam Boiler 

Unit 3 fabric filter outlet exceeds 20 percent opacity as measured 

by a continuous opacity monitor, except that one six-minute 

average per hour of up to 27 percent opacity need not be reported. 

 [40 CFR 60.45(g)(1)] 

iv. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition 

IV.D.4.d above, the Permittee shall report emissions exceeding 

an emission limitation or standard as deviations in accordance 

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

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

5. Performance Testing Requirements 

a. The Permittee shall perform an annual opacity observation of the stack of 

Steam Boiler Unit 3 in accordance with EPA Reference Method 9. 

 [40 CFR 60.8(a) and 46(b)(3)] 

b. The Permittee shall perform annual performance tests for emissions of 

particulate matter from the stack of Steam Boiler Unit 3, using the 

following reference methods and procedures: [40 CFR 60.8(a)] 

i. Reference Method 

EPA Reference Method 5 or 5B shall be used to determine the 

particulate matter concentration (C) at the stack of Steam Boiler 

Unit 3. [40 CFR 60.46(b)(2)] 
TV Renewal Permit No. 53399 Page 55 of 109 May 31, 2012 

APS-Cholla Generating Station 

ii. Emission Rate 

For the purpose of compliance determination, the emission rate 

(E) of PM shall be computed for each run using the following 

equation: [40 CFR 60.46(d)(1)] 

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

 Or 

 E = C Fc (100/%CO2) 

 

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

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

 %O2 = oxygen concentration, percent dry basis. 

 %CO2 = carbon monoxide concentration, percent dry basis. 

 Fd = factor as determined from Method 19 

 Fc = factor as determined in appropriate sections of Method 19. 

iii. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

c. Used Oil and Used Oil Fuel Testing 

 The Permittee shall perform a semiannual sample test for the used oil 

and/or used oil fuel to be burned for flash point and concentrations (ppm) 

of Arsenic, Cadmium, Chromium, Lead, and PCBs, using the analytical 

methods specified in EPA Publication SW-846, Third Edition (document 

number 955-001-00000-1). All sample tests shall be conducted in the 

laboratories certified by the Arizona Department of Health Services. 

 [A.R.S. §49-426.G.2] 

6. Compliance Assurance Monitoring for Particulate Matter 

The Permittee shall conduct the compliance assurance monitoring required in 

Attachment “E” of this permit for Steam Boiler Unit 3. [40 CFR Part 64] 

7. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under 40 CFR 60.42, 40 CFR 60.42, 40 CFR 

60.45, 40 CFR 60.45, 40 CFR 60.46 for the affected source subject to this 

Section. A.A.C. R18-2-325] 

E. Sulfur Dioxide 

 1. Emission Standards/Limitations 

The Permittee shall not cause to be discharged into the atmosphere from the stack 

of Steam Boiler Unit 3 any gases which contain sulfur dioxide in excess of 340 

nanogram per joule heat input (0.8 pounds per million Btu) derived from both 

solid and liquid fossil fuel. 

 [A.A.C. R18-2-903.1, A.A.C. R18-2-903.4, 40 CFR 60.43(a)(1)] 
TV Renewal Permit No. 53399 Page 56 of 109 May 31, 2012 

APS-Cholla Generating Station 

2. Control Requirements

The Permittee shall operate and maintain at all times, including periods of 

startup, shutdown and malfunction, to the extent practicable, Steam Boiler Unit 

3 and the lime slurry FGD system in a manner consistent with good air pollution 

control practice for minimizing sulfur dioxide emissions. The Permittee shall 

inspect and maintain the FGD control device in accordance with manufacturer 

specifications. 

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

[Material Permit Condition identified by underline and italics]

3. Continuous Monitoring SO2 Emissions, and O2/CO2 Content [PSD Permit No. M170843S1-98, Attachment “B”, Condition XV.A] 

a. The Permittee shall calibrate, maintain, and operate a CEMS, and record 

the output of the system, for measuring sulfur dioxide emissions from the 

stack of Steam Boiler Unit 3. [40 CFR 60.49 Da(b), A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

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

monitoring system, and record the output of the system, for measuring 

the O2/CO2 content of the flue gases at the location where SO2 emissions 

are monitored. [40 CFR 60.49Da(d), A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

c. The Permittee shall operate the SO2 and O2/CO2 continuous monitoring 

systems and record data during all periods of operation of Steam Boiler 

Unit 3 including periods of startup, shutdown, malfunction, or emergency 

conditions, except for continuous monitoring system breakdown, repairs, 

calibration checks, and zero and span adjustments. [40 CFR 60.49 Da(e)] 

d. The continuous emission monitoring systems for SO2, and O2/CO2 shall 

meet the following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

[40 CFR 60.13] 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” [40 CFR 60.13] 

(1) Quality control program 

(2) Frequency of testing 
TV Renewal Permit No. 53399 Page 57 of 109 May 31, 2012 

APS-Cholla Generating Station 

iii. Data Reduction

The Permittee shall comply with the data reduction requirements 

of 40 CFR Part 75.10(d)(1). [40 CFR 60.13] 

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. [A.A.C. R18-2-306.A.3.a ] 

e. Sulfur Dioxide Emissions Missing Data Supplemental Procedures 

In addition to the requirements specified in the preceding Condition 

IV.E.3.d of this Attachment, the Permittee shall obtain the SO2 emission 

data for at least 18 hours in at least 22 out of 30 successive boiler 

operating days. If this minimum data requirement cannot be met with 

the continuous monitoring system in use, the Permittee shall supplement 

SO2 emission data with other monitoring systems approved by the 

Director or the following reference methods and procedures: [40 CFR 60.49Da(f), (h) and (j) and PSD Permit 

No. M170843S1-98, Attachment “B”, Condition XV.A] 

i. Reference Method 6 shall be used to determine the SO2

concentration at the same location as the SO2 monitor. 

ii. The emission rate correction factor, integrated bag sampling and 

analysis procedure of Reference Method 3B shall be used to 

determine the O2/CO2 concentration at the same location as the 

O2/CO2 monitor. 

iii. The procedures in Reference Method 19 shall be used to 

compute each 1-hour average concentration in ng/J (pounds per 

million Btu). 

iv. As alternatives, the reference methods and procedures described 

in 40 CFR 49Da(j) may be used. 

4. Recordkeeping and Reporting Requirements

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 3 intends to begin dropping load to go 
TV Renewal Permit No. 53399 Page 58 of 109 May 31, 2012 

APS-Cholla Generating Station 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)]

ii. The summary report form submission required in the preceding 

Condition IV.E.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

e. Definitions 

Periods of excess emissions and monitoring systems (MS) downtime that 

shall be reported are defined as follows: 

SO2 excess emissions are defined as any three-hour period during which, 

the average SO2 emissions from Steam Boiler Unit 3 stack (arithmetic 

average of three contiguous one-hour periods) as measured by a 

continuous monitoring system exceed 0.8 pounds per million Btu for 
both solid and liquid fossil fuel, as specified in Condition IV.E.3 of this 

Attachment. 

 [40 CFR 60.45(g)(2)] 

f Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition IV.C.4.d

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b] 

5. Compliance Demonstration Requirements 

The Permittee shall use the continuous monitoring system described in Condition 

IV.E.3.a of this Attachment to demonstrate compliance with the 0.8 pound per 

million Btu sulfur dioxide emission limitations in Condition IV.E.1 of this 

Attachment on a 3-hour rolling average basis. [A.A.C. R18-2-306.A.3.c] 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under A.A.C. R18-2-903.4, A.A.C.R18-2-

903.1, 40 CFR 60.43(a)(1), 40 CFR 60.49Da, 40 CFR 60.45(g)(2), and PSD 

Permit No.M170843S1-98 for the affected source subject to this Section. [A.A.C. R18-2-325] 

F. Nitrogen Oxides 

1. Emission Limits/Standards 

a. Coal 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 3 any gases which contain nitrogen 

oxides, expressed as NO2 in excess of 300 nanogram per joule heat input 

(0.70 lb per million Btu) derived from solid fossil fuel. 

 [60 CFR 60.44(a)(3)] 

b. Combination Fuels 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 3, when different fossil fuels are burned 

simultaneously in any combination, any gases which contain nitrogen 

oxides in excess of the applicable standard (in ng/J) derived using the 

following proration formula: [40 CFR 60.44(b)] 

zyxw

z(300) y(130) x(86) w(260)

NOx PS



   

Where: 

PSNOx = prorated standard for nitrogen oxides when burning different 

fuels simultaneously, in nanograms per joule heat input derived 

from all fossil fuels fired or from all fossil fuels and wood 

residue fired; 

w = percentage of total heat input derived from lignite; 

TV Renewal Permit No. 53399 Page 59 of 109 May 31, 2012 

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TV Renewal Permit No. 53399 Page 60 of 109 May 31, 2012 

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x = percentage of total heat input derived from gaseous fossil fuel; 

y = percentage of total heat input derived from liquid fossil fuel; and 

z = percentage of total heat input derived from solid fossil fuel (except 

lignite). 

 2. Air Quality Control Requirements 

At all times including periods of startup, shutdown and malfunction, to the extent 

practicable, the Permittee shall operate and maintain Steam Boiler Unit 3 and 

associated low NOx burners in a manner consistent with good air pollution 

control practice for minimizing nitrogen oxides emissions. The Permittee shall 

inspect and maintain the low NOx burners in accordance with manufacturer 

specifications. [A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

 

3. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall calibrate, maintain, and operate CEMS for 

measuring nitrogen oxide (NOx) emissions from the stack of Steam Boiler

Unit 3. [A.A.C. R18-2-306.A.3.c, A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics]

b. The continuous emission monitoring systems for NOx shall meet the 

following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

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

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” [A.A.C. R18-2-306.A.3.c] 

(1) Quality control program 

(2) Frequency of testing 

iii. Data Reduction 

The Permittee shall comply with the data reduction requirements 

of 40 CFR Part 75.10(d)(1). [A.A.C. R18-2-306.A.3.c] 

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 
TV Renewal Permit No. 53399 Page 61 of 109 May 31, 2012 

APS-Cholla Generating Station 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. [A.A.C. R18-2-306.A.3.c] 

4. Recordkeeping and Reporting Requirements

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 3 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)]

ii. The summary report form submission required in the preceding 

Condition IV.F.3.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 
TV Renewal Permit No. 53399 Page 62 of 109 May 31, 2012 

APS-Cholla Generating Station 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

iii. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition 

IV.F.3.d above, the Permittee shall report emissions exceeding 

an emission limitation or standard as deviations in accordance 

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

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

5. Performance Testing Requirements 

The Permittee shall perform annual performance tests for emissions of nitrogen 

oxides from the stack of Steam Boiler Unit 3, using the following reference 

methods and procedures: [40 CFR 60.8(a)] 

a. Nitrogen Oxides 

EPA Reference Method 7 shall be used to determine the nitrogen oxides 

concentration (C) at the stack of Steam Boiler Unit 3. [40 CFR 60.46(b)(5)] 

b. Emission Rate 

For the purpose of compliance determination, the emission rate (E) of 

NOx shall be computed for each run using the following equation: [40 CFR 60.46(d)(1)] 

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

 Or 

E = C Fc (100/%CO2) 

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

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

%O2 = oxygen concentration, percent dry basis. 

%CO2 = carbon monoxide concentration, percent dry basis. 

Fd = factor as determined from Method 19 

Fc = factor as determined in appropriate sections of Method 19. 

c. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 
TV Renewal Permit No. 53399 Page 63 of 109 May 31, 2012 

APS-Cholla Generating Station 

 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under A.A.C. R18-2-903.4, 40 CFR 60.42, 40 

CFR 60.44, 40 CFR 60.44, 40 CFR 60.46, 40 CFR 60.46 for the affected source 

subject to this Section. [A.A.C. R18-2-325] 

G. Carbon Monoxide 

1. Emission Limitations/Standards

a. At all times, excluding periods of startup and shutdown, the Permittee 

shall not cause to be discharged into the atmosphere from the stack of 

Steam Boiler Unit 3, any gases which contain carbon monoxide in excess 

of: 

i 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] 

ii. 0.75 lb per million Btu heat input derived from combustion of 

fuel, on an hourly basis. [A.A.C. R18-2-406.A.5]

b. During periods of startup and shutdown, the Permittee shall not cause to 

be discharged into the atmosphere from the stack of Steam Boiler Unit 3, 

any gases which contain carbon monoxide in excess of 350 pounds per 

hour. [A.A.C. R18-2-406.A.5] 

2. Air Quality Control Requirements [A.A.C. R18-2-406.A.4]

a. At all times, including periods of startup, shutdown and malfunction, to 

the extent practicable, the Permittee shall operate and maintain Steam 

Boiler Unit 3 and associated low NOx burners in a manner consistent 

with good combustion practices for minimizing carbon monoxide 

emissions. A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. For the purpose of this Section, the good combustion practices shall 

include, but is not limited to, the following components: 

i. Good air/fuel mixing in the combustion zone; 

ii. High temperatures and low oxygen levels in the primary 

combustion zone; 

iii. Overall excess oxygen levels high enough to complete 

combustion while maximizing boiler thermal efficiency; and 

iv. Sufficient residence time to complete combustion. 

c. Determination of whether the good combustion practices are being 

implemented for minimizing boiler carbon monoxide emissions will be 

based on information available to the Director which may include, but 

not limited to, monitoring results, review of operation and maintenance 

procedures and records, and inspection of the source. 
TV Renewal Permit No. 53399 Page 64 of 109 May 31, 2012 

APS-Cholla Generating Station 

3. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall install, calibrate, maintain, and operate CEMS at 

each affected steam boiler unit, and record the output of the system, for 

measuring carbon monoxide (CO) and diluent (O2/CO2) emissions from 

exhaust of the boiler’s stack. The output of the CEMS shall be expressed 

in pounds CO per million Btu heat input. 

[A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. The existing diluent (O2/CO2) continuous monitoring systems required 

under Sections IV.E. of Attachment “B” of the permit may be used to 

satisfy the requirement for monitoring of diluent emissions. 

c. All continuous monitoring systems shall meet the following 

requirements: [A.A.C. R18-2-306.A.3.a and 406.A.4]

i. 40 CFR Part 75, Appendix A "Specification and Test 

Procedures" for installation of the NOx monitor shall be used for 

CO monitor by substituting NOx for CO. Due to normal 

combustion variability, a dual range CO monitor shall be 

installed. The RATA specification shall be measured with 2 

decimal places in lb CO per million BTU. 

ii. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” for CO and O2/CO2 monitors 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

iii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality assurance/quality control program 

(2) Frequency of testing 

iv. 40 CFR Part 60 Appendix “F”, Quality Assurance Procedure for 

CO monitor for determining with pounds per hour emission rate 

under Condition IV.G.1.b of this Attachment. 

v. Data Reduction 

The Permittee shall comply with the data reduction requirements 

of 40 CFR Part 75.10(d)(1). 
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APS-Cholla Generating Station 

vi. Missing Data Substitution 

(1) The Permittee shall, in processing any CO emission data 

gaps throughout operation, comply with the appropriate 

provisions in 40 CFR Part 75, Subpart D, “Missing Data 

Substitution Procedures” and Appendix C, “Missing 

Data Estimation Procedures”. For the purpose of this 

Section, when monitor data availability reaches below 

80%, all CO emission data gaps shall be substituted 

using a CO emission rate not less than 0.75 lb per million 

Btu heat input derived from combustion of fuel. 

(2) The Permittee may elect to supplement CO emission data 

with the following USEPA reference methods and 

procedures: 

(a) Reference Method 10 shall be used to determine 

the CO concentration at the same location as the 

CO monitor. 

(b) The emission rate correction factor, integrated 

bag sampling and analysis procedure of 

Reference Method 3B shall be used to determine 

the O2/CO2 concentration at the same location as 

the O2/CO2 monitor. 

(c) The procedures in Reference Method 19 shall be 

used to compute each 1-hour average 

concentration in ng/J (pounds per million Btu). 

(d) As Method 19 does not provide conversion 

factors for carbon monoxide, a conversion factor 

of 7.269×10-8 shall be used to convert parts per 

million (ppm) to pounds per standard cubic foot 

(lb/scf). 

vii. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

d. Except for system breakdowns, repairs, calibration checks, and zero and 

span adjustments, each continuous monitoring system prescribed in this 

Section shall complete a minimum of one cycle of operation (sampling, 

analyzing, and data recording) for each successive 15-minute period.

[A.A.C. R18-2-306.A.3.a and 406.A.4]

e. CO Emissions Compliance Determination 

 [A.A.C. R18-2-406.A.4 and 5]

i. The Permittee shall use CO emission data measured and 
TV Renewal Permit No. 53399 Page 66 of 109 May 31, 2012 

APS-Cholla Generating Station 

recorded by the continuous monitoring systems prescribed in 

this Section to demonstrate compliance with the carbon 

monoxide emission standards set forth in Condition IV.G.1 of 

this Attachment. 

ii. Compliance with Condition IV.G.1.a.i of this Attachment shall 

be based on the average emission rate for 30 successive calendar 

days. A new 30-day average carbon monoxide emission rate 

shall be determined at the end of each calendar day by 

calculating the arithmetic average of all hourly carbon monoxide 

emission rates for the past 30 successive calendar days, except 

for data obtained during periods of startup, shutdown, or 

malfunction. 

iii. The following shall be considered periods of excess emissions: 

(1) Any calendar day for which the 30-day rolling average 

CO emission rate, excluding periods of startup, 

shutdown, or malfunction, as determined by the 

applicable continuous monitoring systems in accordance 

with Condition IV.G.3.e.ii above exceeds the 30-day 

average CO emission limit set forth in Condition 

IV.G.1.a.i of this Attachment. 

(2) Any hour for which the hourly CO emission rate, 

excluding periods of startup, shutdown or malfunction, 

as measured by the applicable continuous monitoring 

systems of this Section exceeds the hourly CO emission 

limit set forth in Condition IV.G.1.a.ii of this 

Attachment. 

(3) Any periods of startup, shutdown or malfunction, for 

which the CO emissions rate for any unit exceeds the 

emission limit set forth in Condition IV.G.1.b of this 

Attachment. 

iv. All excess emissions shall be reported in accordance with 

Section XII, Attachment “A” of the permit. [A.A.C. R18-2-306.A.5.b and 310.01]

f. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this part 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports, and records. [A.A.C. R18-2-306.A.4.a and 406.A.4] 

V. STEAM BOILER UNIT 4 

A. Applicability 

 This section applies to Unit 4 boiler as described in Attachment “C” of this permit. 
TV Renewal Permit No. 53399 Page 67 of 109 May 31, 2012 

APS-Cholla Generating Station 

B. Fuel Requirements 

1. Fuel Limitation [Installation Permit No. 1085] 

The Permittee shall burn only the following fuels in Steam Boiler Unit 4: 

a. Coal; 

b. No. 2 fuel oil for startup and stabilization; 

c. Co-firing of coal and used oil or used oil fuel subject to the requirements 

set forth in Conditions V.B.2.a and b of this Attachment below. 

2. Used Oil and Used Oil Fuel 

a. Specifications 

The used oil or used oil fuel allowed to be burned shall meet the 

following conditions: [A.R.S. §49-426.G.1]

i. The flash point of the oil shall not fall below 100 °F; 

ii. The oil shall not have following constituents in excess of the 

following allowable levels: 

(1) Arsenic 5 ppm 

(2) Cadmium 2 ppm 

(3) Chromium 10 ppm 

(4) Lead 100 ppm 

(5) PCBs 2 ppm 

 (6) Total Halogens 1000 ppm 

b. Limitations [A.R.S. §49-426.G.1] 

(1) The Permittee shall not burn used oil and/or used oil fuel at a 

feed rate greater than twenty (20) gallons per minute while cofiring with coal in Steam Boiler Unit 4 at a minimum of 230 

gross MW; and 

(2) The Permittee shall not burn used oil and/or used oil fuel in 

excess of 200,000 gallons per year. 

C. Operation Procedures 

a. Startup 

During startups of Steam Boiler Unit 4, the fabric filter shall be placed in 

service before startup of any boiler forced draft or induced draft fan. The fabric 

filter may be removed from service just prior to igniting oil fires (startup fuel) 

but must be returned to service before coal fires are placed in the boiler. The 
TV Renewal Permit No. 53399 Page 68 of 109 May 31, 2012 

APS-Cholla Generating Station 

lime slurry FGD system of the unit shall be placed in service after the fabric 

filter is placed in service, and before coal fires are in the boiler. [40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e]

 [Material Permit Condition identified by underline and italics]

b. Shutdown 

During shutdowns of Steam Boiler Unit 4, the fabric filter shall remain in 

service until after the boiler forced draft fans and induced draft fans have been 

turned off. The lime slurry FGD system of the unit shall remain in service until 

coal fires in the boiler are out. 

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

 [Material Permit Condition identified by underline and italics]

c. Malfunction 

 For Steam Boiler Unit 4 with any malfunction of its fabric filter that exceeds 

four hours, if fires are in the boiler, Permittee shall reduce the unit’s load so that 

the fabric filter compartments in service can properly process and treat the 

volume of flue gas being produced. If a malfunction makes it impossible to 

properly process and treat the volume of flue gas being produced, the unit shall 

be shut down. [40 CFR 60.11(d)]

D. Particulate Matter & Opacity 

1. Emission Limits/Standards 

 a. Opacity 

The opacity of emissions from the stack of Steam Boiler Unit 4 shall not 

be greater than 20 percent at all times except for periods of startup, 

shutdown, and malfunction as defined in Conditions I.A.1, 2 and 3 of this 

Attachment, and for one six-minute period per hour of not more than 27 

percent opacity. Opacity readings of portions of plumes which contain 

condensed, uncombined water vapor shall not be used for purposes of 

determining compliance with the opacity standard. 

 [40 CFR 60.42(a)(2), 60.11(c) and 60.11(e)(1) and A.A.C. R18-2-331.A.3.a] 

 [Material Permit Condition identified by underline and italics]

 b. Particulate Matter 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 4 any gases which contain particulate 

matter in excess of 43 nanogram per joule heat input (0.10 lb per million 

Btu) derived from fossil fuel. [40 CFR 60.42(a)(1)] 

 

2. Air Pollution Control Requirements 

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

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

Unit 4 and the fabric filter control device in a manner consistent with good air 

pollution control practice for minimizing particulate matter emissions. The 

Permittee shall inspect and maintain the fabric filter control device in accordance 

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

 [Material Permit Condition identified by underline and italics]
TV Renewal Permit No. 53399 Page 69 of 109 May 31, 2012 

APS-Cholla Generating Station 

3. Continuous Monitoring 

a. The Permittee shall calibrate, maintain, and operate COMS for 

measuring the opacity of emissions. [40 CFR 60.45(a) and A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics] 

b. The continuous opacity monitoring system shall meet the following 

requirements: 

i. 40 CFR 60, Appendix B, Performance Specification 1, 

“Specification and Test Procedures for Opacity Continuous 

Emission Monitoring Systems in Stationary Sources” 

 [40 CFR 60.13]

(1) Apparatus 

(2) Installation Specifications 

(3) Design and Performance Specifications 

(4) Design Specifications Verification Procedure 

(5) Performance Specifications Verification Procedure 

(6) Equations 

ii. Quality assurance requirements: 

(1) Calibration Checks 

The Permittee shall check the zero (or low-level value 

between 0 and 20% of span value) and span calibration 

drifts at least once daily in accordance with a written 

procedure. [40 CFR 60.13(d)(1)] 

(2) Zero and Span Drift Adjustments 

(a) The zero and span shall, as a minimum, be 

adjusted whenever the 24-hr zero drift or 24-hr 

span drift exceeds 4% opacity. [40 CFR 60.13(d)(1)] 

(b) The system shall allow for the amount of excess 

zero and span drift measured at the 24-hour 

interval checks to be recorded and quantified. 

 [40 CFR 60.13(d)(1)] 

(c) The optical surfaces exposed to the effluent 

gases shall be cleaned prior to performing the 

zero and span drift adjustments, except for 

systems using automatic zero adjustments. 

 [40 CFR 60.13(d)(1)] 

(d) For systems using automatic zero adjustments, 

the optical surfaces shall be cleaned when the 

cumulative automatic zero compensation 

exceeds 4% opacity. [40 CFR 60.13(d)(1)] 
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APS-Cholla Generating Station 

(3) System Checks 

A method for producing a simulated zero opacity 

condition and an upscale (span) opacity condition using 

a certified neutral density filter or other related technique 

to produce a known obscuration of the light beam to 

provide a system check of the analyzer internal optical 

surfaces and all electronic circuitry including the lamp 

and photo detector assembly shall be used by the 

Permittee. [40 CFR 60.13(d)(2)] 

(4) Minimum Frequency of Operation 

Except during periods of system breakdowns, repairs, 

calibration checks, and zero and span adjustments, the 

COMS shall be in continuous operation and shall 

complete a minimum of one cycle of sampling and 

analyzing for each successive 10-second period and one 

cycle of data recording for each successive 6-minute 

period. [40 CFR 60.13(e)(1)] 

(5) Data Reduction Procedures [40 CFR 60.13(h)] 

(a) The Permittee shall reduce all data from the 

COMS to 6-minute averages. Six-minute 

opacity averages shall be calculated from 36 or 

more data points equally spaced over each 6-

minute period. 

(b) 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 Condition. An arithmetic or integrated 

average of all data may be used. 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 4 intends to begin dropping load to go 
TV Renewal Permit No. 53399 Page 71 of 109 May 31, 2012 

APS-Cholla Generating Station 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring system performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. 

 [40 CFR 60.7(c) and (d), 45(g), 51Da(j) and 51Da(k)]

ii. The summary report form submission required in the preceding 

Condition V.D.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the steam boiler unit. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

iii. Definitions 

Periods of excess emissions and monitoring systems (MS) 

downtime that shall be reported are defined as follows: 

Opacity excess emissions are defined as any six-minute period 

during which the average opacity of emissions from Steam 

Boiler Unit 4 stack exceeds 20 percent opacity as measured by a 

continuous opacity monitor, except that one six-minute average 
TV Renewal Permit No. 53399 Page 72 of 109 May 31, 2012 

APS-Cholla Generating Station 

per hour of up to 27 percent opacity need not be reported. 

[40 CFR 60.45(g)(1)] 

e. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition V.C.3.d 

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b] 

5. Performance Testing Requirements 

a. Opacity

 The Permittee shall perform an annual opacity observation of the stack of 

Steam Boiler Unit 4 in accordance with EPA Reference Method 9. 

 [40 CFR 60.8(a) and 46(b)(3)] 

b. Particulate Matter 

 The Permittee shall perform annual performance tests for emissions of 

particulate matter from the stack of Steam Boiler Unit 4, using the 

following reference methods and procedures: [40 CFR 60.8(a)] 

i. Reference Method 

EPA Reference Method 5 or 5B shall be used to determine the 

particulate matter concentration at the stack of Steam Boiler 

Unit 4. [40 CFR 60.46(b)(2)] 

ii. Emission Rate [40 CFR 60.46(b)(1)] 

 For the purpose of compliance determination, the emission rate 

(E) of PM shall be computed for each run using the following 

equation: 

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

 Or 

 E = C Fc (100/%CO2) 

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

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

 %O2 = oxygen concentration, percent dry basis. 

 %CO2 = carbon monoxide concentration, percent dry basis. 

 Fd = factor as determined from Method 19 

 Fc = factor as determined in appropriate sections of Method 19. 

c. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

6. Compliance Assurance Monitoring for Particulate Matter 

 The Permittee shall conduct compliance assurance monitoring as required in 
TV Renewal Permit No. 53399 Page 73 of 109 May 31, 2012 

APS-Cholla Generating Station 

Attachment “E” of this permit for Steam Boiler Unit 4. [40 CFR Part 64]

7. Used Oil and Used Oil Fuel Testing 

The Permittee shall perform a semiannual sample test for the used oil and/or used 

oil fuel to be burned for flash point and concentrations (ppm) of Arsenic, 

Cadmium, Chromium, Lead, and PCBs, using the analytical methods specified in 

EPA Publication SW-846, Third Edition (document number 955-001-00000-1). 

All sample tests shall be conducted in the laboratories certified by the Arizona 

Department of Health Services. [A.R.S. §49-426.G.2]

8. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under 40 CFR 60.42, 40 CFR 60.45, and 40 

CFR 60.46 and 40 CFR Part 64 for the affected source subject to this Section. 

 [A.A.C. R18-2-325] 

E. Sulfur Dioxide 

1. Emission Limits/Standards 

 The Permittee shall not cause to be discharged into the atmosphere from the 

stack of Steam Boiler Unit 4 any gases which contain sulfur dioxide in excess of 

340 nanograms per joule heat input (0.8 pounds per million Btu) derived from 

solid or liquid fossil fuel. [A.A.C. R18-2-903.1 and 40 CFR 60.43(a)(1)] 

2. Air Pollution Control Requirements 

 

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

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

Unit 4 and the lime slurry FGD system in a manner consistent with good air 

pollution control practice for minimizing sulfur dioxide emissions. The 

Permittee shall inspect and maintain the FGD control device in accordance with 

manufacturer specifications. 

 [Installation Permit No. 1247, 40 CFR 60.11(d) and A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

3. Continuous Monitoring SO2 and O2/CO2 Content 

a. The Permittee shall calibrate, maintain, and operate CEMS for 

measuring sulfur dioxide and O2/CO2 emissions from the stack of Steam 

Boiler Unit 4. [40 CFR 60.45(a) and A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics] 

 

b. The continuous emission monitoring systems for SO2 and O2/CO2 shall 

meet the following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” 

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

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 
TV Renewal Permit No. 53399 Page 74 of 109 May 31, 2012 

APS-Cholla Generating Station 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

 

(1) Quality control program 

(2) Frequency of testing 

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

iii. Data Reduction 

 

The Permittee shall comply with the data reduction requirements 

of 40 CFR Part 75.10(d)(1). [A.A.C. R18-2-306.A.3.c] 

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

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

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 4 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring systems performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 
TV Renewal Permit No. 53399 Page 75 of 109 May 31, 2012 

APS-Cholla Generating Station 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. [40 CFR 60.7(c) and (d) and 45(g)] 

ii. The summary report form submission required in the preceding 

Condition V.E.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the affected facility. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

iii. Definitions 

Periods of excess emissions and monitoring systems (MS) 

downtime that shall be reported is defined as follows: 

SO2 excess emissions are defined as any three-hour period 

during which the average SO2 emissions from Steam Boiler Unit 

4 stack (arithmetic average of three contiguous one-hour 

periods) as measured by a continuous monitoring system exceed 

0.8 pound per million Btu, as specified in Condition V.E.3 of 

this Attachment. [40 CFR 60.45(g)(2)] 

e. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition V.E.4.d 

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b] 

 
TV Renewal Permit No. 53399 Page 76 of 109 May 31, 2012 

APS-Cholla Generating Station 

5. Performance Testing Requirements 

The Permittee shall perform annual performance tests for emissions of sulfur 

dioxide from the stack of Steam Boiler Unit 4, using the following reference 

methods and procedures: [40 CFR 60.8(a)] 

a. Reference Method 

EPA Reference Method 6 shall be used to determine the SO2

concentration at the stack of Steam Boiler Unit 4. [40 CFR 60.46(b)(4)] 

b. Emission Rate [40 CFR 60.46(b)(1)] 

For the purpose of compliance determination, the emission rate (E) of 

SO2 shall be computed for each run using the following equation: 

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

 Or 

E = C Fc (100/%CO2) 

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

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

%O2 = oxygen concentration, percent dry basis. 

%CO2 = carbon monoxide concentration, percent dry basis. 

Fd = factor as determined from Method 19 

Fc = factor as determined in appropriate sections of Method 19. 

c. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under 40 CFR 60.43, 40 CFR 60.45, 40 CFR 

60.46 and Installation permit #1247 for the affected sources subject to this 

Section. [A.A.C. R18-2-325]

F. Nitrogen Oxide(s) 

 1. Emission Standards/Limitations 

 a. Coal 

The Permittee shall not cause to be discharged into the atmosphere from 

the stack of Steam Boiler Unit 4 any gases which contain nitrogen 

oxides, expressed as NO2 in excess of 300 nanogram per joule heat input 

(0.70 lb per million But) derived from solid fossil fuel. [40 CFR 60.44(a)(3)] 

 b. Combination Fuels 

The Permittee shall not cause to be discharged into the atmosphere from 
the stack of Steam Boiler Unit 4, when different fossil fuels are burned 

simultaneously in any combination, any gases which contain nitrogen 

oxides in excess of the applicable standard (in ng/J) derived using the 

following prorating formula: 

 [40 CFR 60.44(b)] 

zyxw

z(300) y(130) x(86) w(260)

NOx PS



   

Where: 

PSNOx= prorated standard for nitrogen oxides when burning different 

fuels simultaneously, in nanograms per joule heat input derived 

from all fossil fuels fired or from all fossil fuels and wood 

residue fired; 

w = percentage of total heat input derived from lignite; 

x = percentage of total heat input derived from gaseous fossil fuel; 

y = percentage of total heat input derived from liquid fossil fuel; and 

z = percentage of total heat input derived from solid fossil fuel 

(except lignite). 

 2. Air Quality Control Requirements 

At all times including periods of startup, shutdown and malfunction, to the extent 

practicable, the Permittee shall operate and maintain Steam Boiler Unit 4 and 

associated low NOx burners in a manner consistent with good air pollution 

control practice for minimizing nitrogen oxides emissions. The Permittee shall 

inspect and maintain the low NOx burners in accordance with manufacturer 

specifications. [A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

3. Continuous Monitoring NOx Emissions 

a. The Permittee shall calibrate, maintain and operate CEMS for measuring 

nitrogen oxide (NOx) emissions from the stack of Steam Boiler Unit 4. [A.A.C. R18-2-306.A.3.c, A.A.C. R18-2-331.A.3.c] [Material Permit Condition identified by underline and italics] 

 

b. The continuous emission monitoring systems for NOx shall meet the 

following requirements: 

i. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” [A.A.C. R18-2-306.A.3.c] 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

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APS-Cholla Generating Station 

ii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” [A.A.C. R18-2-306.A.3.c] 

(1) Quality control program 

(2) Frequency of testing 

iii. Data Reduction [A.A.C. R18-2-306.A.3.c] 

The Permittee shall comply with the data reduction requirements 

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

iv. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

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

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

4. Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this section 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports and records. [40 CFR 60.7(f)] 

b. The Permittee shall comply with all the recordkeeping and reporting 

requirements of 40 CFR Part 75 Subparts F and G, respectively. 

 [40 CFR 60.7] 

c. The Permittee shall record in a permanent log for each shutdown, the 

date and time Steam Boiler Unit 4 intends to begin dropping load to go 

off line. The log shall be retained for at least five (5) years following the 

date of each shutdown. [A.A.C. R18-2-306.A.4] 

d. Quarterly excess emissions and monitoring systems performance reports 

i. The Permittee shall submit an excess emissions and monitoring 

systems performance (MSP) report and/or a summary report 

form to the Department for every calendar quarter, unless the 

total duration of excess emissions for the reporting period is less 

than 1 percent of the total operating time for the reporting period 

and the continuous monitoring system downtime for the 

reporting period is less than 5 percent of the total operating time 

for the reporting period, in which case only the summary report 

form shall be submitted and the excess emissions report need not 

be submitted unless requested by the Department. All quarterly 

reports shall be postmarked by the 30th day following the end of 

each calendar quarter. [40 CFR 60.7(c) and (d) and 45(g)] 
TV Renewal Permit No. 53399 Page 79 of 109 May 31, 2012 

APS-Cholla Generating Station 

ii. The summary report form submission required in the preceding 

Condition V.F.4.d.i shall be in the format specified in 40 CFR 

60.7(d). Each excess emission and MSP report shall include the 

following information: [40 CFR 60.7(c)] 

(1) The magnitude of excess emissions computed, any 

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

commencement and completion of each time period of 

excess emissions. The process operating time during the 

reporting period. 

(2) Specific identification of each period of excess 

emissions that occurs during startups, shutdowns, and 

malfunctions of the affected facility. The nature and 

cause of any malfunction (if known), the corrective 

action taken or preventative measures adopted. 

(3) The date and time identifying each period during which 

the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the 

system repairs or adjustments. 

(4) When no excess emissions have occurred or the 

continuous monitoring system(s) have not been 

inoperative, repaired, or adjusted, such information shall 

be stated in the report. 

f. Emission deviations reporting requirements 

In addition to the quarterly reporting required under Condition V.F.4.d 

above, the Permittee shall report emissions exceeding an emission 

limitation or standard as deviations in accordance with Section XII.B of 

Attachment “A” of this permit. [A.A.C. R18-2-306.A.5.b] 

5. Performance Testing Requirements 

The Permittee shall perform annual performance tests for emissions of nitrogen 

oxides from the stack of Steam Boiler Unit 4, using the following reference 

methods and procedures: [40 CFR 60.8(a)] 

a. Reference Method 

EPA Reference Method 7 shall be used to determine the NOx

concentration at the stack of Steam Boiler Unit 4. [40 CFR 60.46(b)(5)] 

b. Emission Rate [40 CFR 60.46(b)(1)] 

For the purpose of compliance determination, the emission rate (E) of 

NOx shall be computed for each run using the following equation: 

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

 Or 

E = C Fc (100/%CO2) 
TV Renewal Permit No. 53399 Page 80 of 109 May 31, 2012 

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

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

%O2 = oxygen concentration, percent dry basis. 

%CO2 = carbon monoxide concentration, percent dry basis. 

Fd = factor as determined from Method 19 

Fc = factor as determined in appropriate sections of Method 19. 

c. The Permittee may conduct the annual performance tests using 

alternatives described in 40 CFR 60.46(d). 

6. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with the 

applicable requirements prescribed under 40 CFR 60.44, and 40 CFR 60.46 for 

the affected source subject to this Section. [A.A.C. R18-2-325] 

G. Carbon Monoxide 

1. Emission Limitations/Standards

a. At all times, excluding periods of startup and shutdown, the Permittee 

shall not cause to be discharged into the atmosphere from the stack of 

Steam Boiler Unit 4, any gases which contain carbon monoxide in excess 

of: 

i 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] 

ii. 0.75 lb per million Btu heat input derived from combustion of 

fuel, on an hourly basis. [A.A.C. R18-2-406.A.5] 

b. During periods of startup and shutdown, the Permittee shall not cause to 

be discharged into the atmosphere from the stack of Steam Boiler Unit 4, 

any gases which contain carbon monoxide in excess of 400 pounds per 

hour. [A.A.C. R18-2-406.A.5] 

2. Air Quality Control Requirements [A.A.C. R18-2-406.A.4]

a. At all times, including periods of startup, shutdown and malfunction, to 

the extent practicable, the Permittee shall operate and maintain Steam 

Boiler Unit 4 and associated low NOx burners in a manner consistent 

with good combustion practices for minimizing carbon monoxide 

emissions. A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. For the purpose of this Section, the good combustion practices shall 

include, but is not limited to, the following components: 

i. Good air/fuel mixing in the combustion zone; 

ii. High temperatures and low oxygen levels in the primary 

combustion zone; 
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APS-Cholla Generating Station 

iii. Overall excess oxygen levels high enough to complete 

combustion while maximizing boiler thermal efficiency; and 

iv. Sufficient residence time to complete combustion. 

c. Determination of whether the good combustion practices are being 

implemented for minimizing boiler carbon monoxide emissions will be 

based on information available to the Director which may include, but 

not limited to, monitoring results, review of operation and maintenance 

procedures and records, and inspection of the source. 

3. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall install, calibrate, maintain, and operate CEMS at 

each affected steam boiler unit, and record the output of the system, for 

measuring carbon monoxide (CO) and diluent (O2/CO2) emissions from 

exhaust of the boiler’s stack. The output of the CEMS shall be expressed 

in pounds CO per million Btu heat input. 

[A.A.C. R18-2-306.A.3.a, 331.A.3.c and 406.A.4]

 [Material Permit Condition identified by underline and italics]

b. The existing diluent (O2/CO2) continuous monitoring systems required 

under Sections V.E. of Attachment “B” of the permit may be used to 

satisfy the requirement for monitoring of diluent emissions. 

c. All continuous monitoring systems shall meet the following 

requirements: [A.A.C. R18-2-306.A.3.a and 406.A.4]

i. 40 CFR Part 75, Appendix A "Specification and Test 

Procedures" for installation of the NOx monitor shall be used for 

CO monitor by substituting NOx for CO. Due to normal 

combustion variability, a dual range CO monitor shall be 

installed. The RATA specification shall be measured with 2 

decimal places in lb CO per million BTU. 

ii. 40 CFR Part 75, Appendix A, “Specification and Test 

Procedures” for CO and O2/CO2 monitors 

(1) Installation and measurement location 

(2) Equipment specifications 

(3) Performance specifications 

(4) Data acquisition and handling systems 

(5) Calibration gas 

(6) Certifications tests and procedures 

(7) Calculations 

iii. 40 CFR Part 75, Appendix B, “Quality Assurance and Quality 

Control Procedure” 

(1) Quality assurance/quality control program 

(2) Frequency of testing 
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iv. 40 CFR Part 60 Appendix “F”, Quality Assurance Procedure for 

CO monitor for determining with pounds per hour emission rate 

under Condition V.G.1.b of this Attachment. 

v. Data Reduction 

The Permittee shall comply with the data reduction requirements 

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

vi. Missing Data Substitution 

(1) The Permittee shall, in processing any CO emission data 

gaps throughout operation, comply with the appropriate 

provisions in 40 CFR Part 75, Subpart D, “Missing Data 

Substitution Procedures” and Appendix C, “Missing 

Data Estimation Procedures”. For the purpose of this 

Section, when monitor data availability reaches below 

80%, all CO emission data gaps shall be substituted 

using a CO emission rate not less than 0.75 lb per million 

Btu heat input derived from combustion of fuel. 

(2) The Permittee may elect to supplement CO emission data 

with the following USEPA reference methods and 

procedures: 

(a) Reference Method 10 shall be used to determine 

the CO concentration at the same location as the 

CO monitor. 

(b) The emission rate correction factor, integrated 

bag sampling and analysis procedure of 

Reference Method 3B shall be used to determine 

the O2/CO2 concentration at the same location as 

the O2/CO2 monitor. 

(c) The procedures in Reference Method 19 shall be 

used to compute each 1-hour average 

concentration in ng/J (pounds per million Btu). 

(d) As Method 19 does not provide conversion 

factors for carbon monoxide, a conversion factor 

of 7.269×10-8 shall be used to convert parts per 

million (ppm) to pounds per standard cubic foot 

(lb/scf). 

vii. 40 CFR Part 75, Appendix F, “Conversion Procedures” 

The Permittee shall convert all hourly pollutant and diluent data 

to the applicable emissions standard utilizing the procedures of 

40 CFR Part 75, Appendix F. 

d. Except for system breakdowns, repairs, calibration checks, and zero and 

span adjustments, each continuous monitoring system prescribed in this 
TV Renewal Permit No. 53399 Page 83 of 109 May 31, 2012 

APS-Cholla Generating Station 

Section shall complete a minimum of one cycle of operation (sampling, 

analyzing, and data recording) for each successive 15-minute period.

[A.A.C. R18-2-306.A.3.a and 406.A.4] 

e. CO Emissions Compliance Determination [A.A.C. R18-2-406.A.4 and 5]

i. The Permittee shall use CO emission data measured and 

recorded by the continuous monitoring systems prescribed in 

this Section to demonstrate compliance with the carbon 

monoxide emission standards set forth in Condition IV.G.1 of 

this Attachment. 

ii. Compliance with Condition V.G.1.a.i of this Attachment shall 

be based on the average emission rate for 30 successive calendar 

days. A new 30-day average carbon monoxide emission rate 

shall be determined at the end of each calendar day by 

calculating the arithmetic average of all hourly carbon monoxide 

emission rates for the past 30 successive calendar days, except 

for data obtained during periods of startup, shutdown, or 

malfunction. 

iii. The following shall be considered periods of excess emissions: 

(1) Any calendar day for which the 30-day rolling average 

CO emission rate, excluding periods of startup, 

shutdown, or malfunction, as determined by the 

applicable continuous monitoring systems in accordance 

with Condition V.G.3.e.ii above exceeds the 30-day 

average CO emission limit set forth in Condition 

V.G.1.a.i of this Attachment. 

(2) Any hour for which the hourly CO emission rate, 

excluding periods of startup, shutdown or malfunction, 

as measured by the applicable continuous monitoring 

systems of this Section exceeds the hourly CO emission 

limit set forth in Condition V.G.1.a.ii of this Attachment. 

(3) Any periods of startup, shutdown or malfunction, for 

which the CO emissions rate for any unit exceeds the 

emission limit set forth in Condition V.G.1.b of this 

Attachment. 

iv. All excess emissions shall be reported in accordance with 

Section XII, Attachment “A” of the permit. [A.A.C. R18-2-306.A.5.b and 310.01]

f. The Permittee shall maintain a file of all measurements, including 

continuous monitoring system, monitoring device, and performance 

testing measurements; all continuous monitoring system performance 

evaluations; all continuous monitoring system or monitoring device 

calibration checks; adjustments and maintenance performed on these 

systems or devices; and all other information required by this part 

recorded in a permanent form suitable for inspection. The file shall be 

retained for at least five years following the date of such measurements, 

maintenance, reports, and records. 

[A.A.C. R18-2-306.A.4.a and 406.A.4] 
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APS-Cholla Generating Station 

VI. COOLING TOWERS 3 AND 4 

A. Applicability 

This section applies to Cooling Towers #3 and #4 as described in Attachment “C” of this 

permit. 

B. Opacity Requirements 

1. Emission Limits 

The Permittee shall not cause, allow or permit to be emitted into the atmosphere 

any plume or effluent from Cooling Tower 3 or 4 the opacity of which exceeds 

20 percent, measured in accordance with EPA Reference Method 9. Where the 

presence of uncombined water is the only reason for an exceedance of any visible 

emissions requirements, such exceedance shall not constitute a violation. [A.A.C. R18-2-702.B.3 and C] 

2. Monitoring, Recordkeeping and Reporting Requirements 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

for the cooling towers consistent with Condition I.H of this Attachment. 

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

3. Permit Shield 

Compliance with this Section shall be deemed compliance with A.A.C. R18-2-

702.B and C for the affected sources subject to this Section. [A.A.C. R18-2-325] 

C. Particulate Matter

1. Emission Limits/Standards

 The Permittee shall not cause, allow or permit the emission of particulate matter 

from Cooling Tower 3 or 4 in excess of the amounts calculated by the following 

equation: [A.A.C. R18-2-730.A.1(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. 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. Monitoring, Recordkeeping and Reporting Requirements 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

for the cooling towers consistent with Condition I.H of this Attachment. 

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

3. Permit Shield 

Compliance with this Section shall be deemed compliance with A.A.C. R18-2-
TV Renewal Permit No. 53399 Page 85 of 109 May 31, 2012 

APS-Cholla Generating Station 

730.A.1(b) for the affected sources subject to this Section. [A.A.C. R18-2-325] 

VII. COAL PREPARATION PLANT 

 

A. Equipment Subject to A.A.C Rules 

 1. Applicability 

This section is applicable to all equipment in the Coal Preparation Plant except 

the Coal Handling System -New Track as described in the equipment list in 

Attachment “C” of this permit. 

2. Opacity 

 

a. Emission Limits/Standards 

 The Permittee shall not cause, allow or permit to be emitted into the 

atmosphere any plume or effluent from the equipment covered by this 

section, the opacity of which exceeds 20 percent, measured in accordance 

with EPA Reference Method 9. Where the presence of uncombined 

water is the only reason for an exceedance of any visible emissions 

requirements, such exceedance shall not constitute a violation. 

[A.A.C. R18-2-702.B.3 and C] 

b. Monitoring, Recordkeeping and Reporting Requirements 

 The Permittee shall conduct a weekly Visible Emissions Observation 

Procedure for any point source, non-point sources, or fugitive emissions 

for the equipment covered by this Section consistent with Condition I.H 

of this Attachment. [A.A.C. R18-2-306.A.3.c] 

3. Particulate Matter 

a. Emission Limits/Standards [A.A.C. R18-2-716.B & D]

 The Permittee shall not cause, allow or permit the discharge of particulate 

matter into the atmosphere in any one hour from the equipment covered 

by this section in total quantities in excess of the amounts calculated by 

the following equation: 

 

E = 55.0 P0.11 – 40 

Where: 

E = The maximum allowable particulate emissions rate in poundsmass 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 emissions 

of particulate matter. 

b. Air Pollution Control Requirements 

i. The Permittee shall operate and maintain water 
TV Renewal Permit No. 53399 Page 86 of 109 May 31, 2012 

APS-Cholla Generating Station 

spraying/chemical dust suppression at the feeders during railcar 

unloading, at the screen feeders during screening, and at the 

coal piles during stockpiling in a manner consistent with good 

air pollution control practice for minimizing particulate matter 

emissions from the coal preparation plant. [Installation Permit No. 1160 & A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

ii. The Permittee shall operate and maintain dust collectors for 

Crusher Tower #1, Crusher Tower #2, and Transfer Tower #3, 

in a manner consistent with good air pollution control practice 

for minimizing particulate emissions.

 [Installation Permit No. 1160 & A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

iii. The water spraying/chemical dust suppressing system and dust 

collectors for the coal preparation plant shall be operated and 

maintained in accordance with the manufacturer’s specifications. 

These specifications shall be on file and shall be readily 

available for inspection by the Department. 

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

iv. The Permittee shall maintain records of emissions control 

equipment maintenance performed on the water 

spraying/chemical dust suppressing system and dust collectors. 

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

4. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with 

A.A.C. R18-2-702.B and 716.B and D and Installation Permit No. 1160 for the 

sources subject to this Section. [A.A.C. R18-2-325] 

B. Equipment subject to New Source Performance Standards 

 (New Track Unloading Hopper and Conveyor 12A) 

 1. Applicability 

This section is applicable to all equipment under the Coal Handling System – 

New Track as described in the equipment list in Attachment “C” of this permit. 

2. Opacity 

 a. Emission Limitation/Standards 

The Permittee shall not cause to be emitted to the atmosphere from the 

equipment covered by this section, gases which exhibit opacity greater 20 

percent. [40 CFR 60.252(c) & A.A.C. R18-2-331.A.3.f] 

 [Material Permit Condition identified by underline and italics]

 b. Air Pollution Control Requirements 

The Permittee shall operate and maintain water spraying/chemical dust 

suppression at the feeders during rail car unloading and at the drop 

point of Conveyor 12A in a manner consistent with good air pollution 

control practice for minimizing particulate matter emissions.

 [A.A.C. R18-2-306.A.2 & A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics] 
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 c. Monitoring, Recordkeeping, and Reporting Requirements 

i. The Permittee shall conduct a weekly Visible Emissions 

Observation Procedure for the equipment covered by this 

Section consistent with Condition I.H of this Attachment. 

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

ii. The water spraying/chemical dust suppressing system and dust 

collectors for the coal preparation plant shall be operated and 

maintained in accordance with the manufacturer’s specifications. 

These specifications shall be on file and shall be readily available 

for inspection by the Department. 

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

iii. The Permittee shall maintain records of emissions control 

equipment maintenance performed on the water 

spraying/chemical dust suppressing system and dust collectors. 

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

 d. Performance Testing Requirements 

The Permittee shall conduct initial performance tests for opacity in 

accordance with the provisions of 40 CFR 60.8. [A.A.C. R18-2-312] 

VIII. FLY ASH HANDLING FACILITY 

A. Applicability 

This section applies to fly ash handling equipment as described in Attachment “C” of this 

permit. 

B. Opacity 

1. Emission Limits/Standards 

The Permittee shall not cause, allow or permit to be emitted into the atmosphere 

any plume or effluent from the fly ash silo vent the opacity of which exceeds 20 

percent, measured in accordance with EPA Reference Method 9. Where the 

presence of uncombined water is the only reason for an exceedance of any visible 

emissions requirements, such exceedance shall not constitute a violation. [A.A.C. R18-2-702.B.3 and C] 

2. Monitoring, Recordkeeping and Reporting Requirements 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

for any point/non-point sources, or fugitive emissions at the fly ash handling 

facility consistent with Condition I.H of this Attachment. [A.A.C. R18-2-306.A.3.c] 

C. Particulate Matter 

1. Emission Limits/Standards 

The Permittee shall not cause, allow or permit the discharge of particulate matter 

into the atmosphere in any one hour from the fly ash silo baghouse exhaust vent 

in total quantities in excess of the amounts calculated by the following equation: 
TV Renewal Permit No. 53399 Page 88 of 109 May 31, 2012 

APS-Cholla Generating Station 

 

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. 

 [A.A.C. R18-2-730.A.1.b and B]

2. Air Pollution Control Requirements 

The Permittee shall operate and maintain at all times the baghouse in a manner 

consistent with good air pollution control practice for minimizing particulate 

matter emissions from the fly ash silo vent. The Permittee shall inspect and 

maintain the fabric filter control device in accordance with manufacturer 

specifications. [Installation Permit No. 1244, A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics] 

3. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain and operate the fly ash silo baghouse in 

accordance with the manufacturer’s specification. These specifications 

shall be on file and shall be readily available for inspection by the 

Department. [Installation Permit No. 1244] 

b. The Permittee shall maintain records of emissions control equipment 

maintenance performed on the fly ash silo baghouse. 

 [Installation Permit No. 1244] 

D. Permit Shield 

Compliance with the terms of this Section shall be deemed compliance with A.A.C. R18-

2-702.B, A.A.C. R18-2-730.A.1.b and B, and Installation Permit No. 1244 for the 

affected sources subject to this Section. [A.A.C. R18-2-325] 

IX. LIME HANDLING AND SLAKING 

A. Applicability 

This section applies to Lime handling and Slaking equipment as described in Attachment 

“C” of this permit. 

B. Opacity 

1. Emission Limits/Standards 

The Permittee shall not cause, allow or permit to be emitted into the atmosphere 

any plume or effluent from the lime silo baghouse exhaust vent or the lime 

slaking wet scrubber exhaust vent the opacity of which exceeds 20 percent, 

measured in accordance with EPA Reference Method 9. Where the presence of 

uncombined water is the only reason for an exceedance of any visible emissions 

requirements, such exceedance shall not constitute a violation. 

 [A.A.C. R18-2-702.B.3 and C] 

2. Monitoring, Recordkeeping and Reporting Requirements 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

for any point/non-point sources, or fugitive emissions at the lime handling and 
TV Renewal Permit No. 53399 Page 89 of 109 May 31, 2012 

APS-Cholla Generating Station 

slaking facility consistent with Condition I.H of this attachment. 

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

3. Permit Shield 

 

Compliance with the terms of this Section shall be deemed compliance with 

A.A.C. R18-2-702.B for the affected sources subject to this Section. 

 [A.A.C. R18-2-325] 

C. Particulate Matter 

1. Emission Limits/Standards 

The Permittee shall not cause, allow or permit the discharge of particulate matter 

into the atmosphere in any one hour from the lime silo baghouse exhaust vent or 

the lime slaking wet scrubber exhaust vent in total quantities in excess of the 

amounts calculated by the following equation: [A.A.C. R18-2-730.A.1.a and B]

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. Air Pollution Control Requirements 

The Permittee shall, during operation of the lime handling and slaking facility, 

operate and maintain a wet scrubber on the vent of each operating lime slaker 

and a baghouse on the vent of each operating lime silo in a manner consistent 

with good air pollution control practice for minimizing particulate matter 

emissions from those vents. The Permittee shall inspect and maintain the wet 

scrubber control device in accordance with manufacturer specifications. 

 [Installation Permit No. 1247, A.A.C. R18-2-331.A.3.e] 

 [Material Permit Condition identified by underline and italics]

3. Monitoring, Recordkeeping and Reporting Requirements [A.A.C. R18-2-306.A.4] 

a. The Permittee shall maintain and operate the lime silos baghouse and 

lime slaker vent wet scrubber in accordance with the manufacturer’s 

specification. These specifications shall be on file and shall be readily 

available for inspection by the Department. 

b. The Permittee shall maintain records of emissions control equipment 

maintenance performed on the lime silo baghouse and lime slaker vent 

wet scrubber. 

4. Permit Shield 

 

Compliance with the terms of this Section shall be deemed compliance with 

A.A.C. R18-2-730.A.1.a and B and Installation Permit No. 1247 for the affected 

sources subject to this Section. [A.A.C. R18-2-325] 
TV Renewal Permit No. 53399 Page 90 of 109 May 31, 2012 

APS-Cholla Generating Station 

X. FUGITIVE DUST SOURCES 

A. Emission Limits/Standards 

1. Open Areas, Roadways & Streets, Storage Piles, and Material Handling 

a. Opacity of emissions from any fugitive dust non-point source shall not 

be greater than 40% measured in accordance with the Arizona Testing 

Manual, Reference Method 9. [A.A.C. R18-2-614] 

b. The Permittee shall not cause, allow or permit visible emissions from any 

fugitive dust point source, in excess of 20 percent opacity. 

 [A.A.C-R18-2-702.B] 

c. The Permittee shall employ the following reasonable precautions to 

prevent excessive amounts of particulate matter from becoming airborne: 

i. Keep dust and other types of air contaminants to a minimum in 

an open area where construction operations, repair operations, 

demolition activities, clearing operations, leveling operations, or 

any earth moving or excavating activities are taking place, by 

good modern practices such as using an approved dust 

suppressant or adhesive soil stabilizer, paving, covering, 

landscaping, continuous wetting, detouring, barring access, or 

other acceptable means; [A.A.C. R18-2-604.A] 

ii. Keep dust to a minimum from driveways, parking areas, and 

vacant lots where motor vehicular activity occurs by using an 

approved dust suppressant, or adhesive soil stabilizer, or by 

paving, or by barring access to the property, or by other 

acceptable means; [A.A.C. R18-2-604.B] 

iii. Keep dust and other particulates to a minimum by employing 

dust suppressants, temporary paving, detouring, wetting down or 

by other reasonable means when a roadway is repaired, 

constructed, or reconstructed; [A.A.C. R18-2-605.A] 

iv. Take reasonable precautions, such as wetting, applying dust 

suppressants, or covering the load when transporting material 

likely to give rise to airborne dust; [A.A.C. R18-2-605.B] 

v. Take reasonable precautions, such as the use of spray bars, 

wetting agents, dust suppressants, covering the load, and hoods 

when crushing, handling, or conveying material likely to give 

rise to airborne dust; [A.A.C. R18-2-606] 

vi. Take reasonable precautions such as chemical stabilization, 

wetting, or covering when organic or inorganic dust producing 

material is being stacked, piled, or otherwise stored; 

 [A.A.C. R18-2-607.A] 

vii. Operate stacking and reclaiming machinery utilized at storage 

piles at all times with a minimum fall of material, or with the use 

of spray bars and wetting agents; [A.A.C. R18-2-607.B] 
TV Renewal Permit No. 53399 Page 91 of 109 May 31, 2012 

APS-Cholla Generating Station 

viii. Any other method as proposed by the Permittee and approved by 

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

2. Open Burning 

 

Except as provided in A.A.C. R18-2-602.C(1), C(3), and C(4), and except when 

permitted to do so by either ADEQ or the local officer delegated the authority for 

issuance of open burning permits the Permittee shall not conduct open burning. [A.A.C. R18-2-602] 

B. Monitoring, Recordkeeping and Reporting Requirements 

1. Open Areas, Roadways & Streets, Storage Piles and Material Handling 

The Permittee shall maintain records of the dates on which any of the activities 

listed in Conditions X.A.1.c.i through viii of this Attachment were performed and 

control measures adopted. [A.A.C. R18-2-306.A.4] 

2. Weekly Opacity Survey 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

for all fugitive dust sources at open areas, roadways and streets, storage piles and 

material handling facilities consistent with Condition I.H of this Attachment. [A.A.C. R18-2-306.A.3.c] 

3. Open Burning 

The monitoring requirements for open burning may be complied with by 

maintaining copies of all open burning permits on file. [A.A.C. R18-2-306.A.4] 

C. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with A.A.C. 

R18-2-604.A, A.A.C. R18-2-604.B, A.A.C. R18-2-605, A.A.C. R18-2-606, A.A.C. R18-

2-607, A.A.C. R18-2-614 and A.A.C. R18-2-702.B. [A.A.C. R18-2-325] 

XI. MOBILE SOURCE REQUIREMENTS 

A. Applicability

The requirements of this Section 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 agricultural 

equipment used in normal farm operations. Mobile sources shall not include portable 

sources as defined in A.A.C. R18-2-101.90. [A.A.C.R18-2-801.A] 

B. Particulate Matter and Opacity

1. Emission Limitations/Standards 

a. Off-Road Machinery 

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%. Visible 

emissions when starting cold equipment shall be exempt from this 

requirement for the first ten minutes. Off-road machinery shall include 
TV Renewal Permit No. 53399 Page 92 of 109 May 31, 2012 

APS-Cholla Generating Station 

trucks, graders, scrapers, rollers, and other construction and mining 

machinery not normally driven on a completed public roadway. 

[A.A.C.R18-2-802.A and -802.B] 

b. Roadway and Site Cleaning Machinery 

(1) 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%. Visible emissions 

when starting cold equipment shall be exempt from this 

requirement for the first ten minutes. [A.A.C.R18-2-804.A] 

(2) The Permittee shall take reasonable precautions, such as the use 

of dust suppressants, before the cleaning of a 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. [A.A.C. R18-2-804.B] 

c. Unless otherwise specified, no mobile source shall emit smoke or dust 

the opacity of which exceeds 40%. [A.A.C.R18-2-801.B] 

2. Recordkeeping Requirement 

The Permittee shall keep a record of all emissions related maintenance activities 

performed on the Permittee's mobile sources stationed at the facility as per 

manufacturer's specifications. [A.A.C.R18-2-306.A.5.a] 

3. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with 

A.A.C. R18-2-801, A.A.C. R18-2-802.A, A.A.C. R18-2-802.B, A.A.C. R18-2-

804.A and A.A.C. R18-2-804.B. [A.A.C.R18-2-325] 

XII. OTHER PERIODIC ACTIVITIES 

A. Abrasive Blasting

1. Particulate Matter and Opacity 

a. Emission Limitations/Standards 

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: 

(1) Wet blasting; 

(2) Effective enclosures with necessary dust collecting equipment; 

(3) Any other method approved by the Director. 

[A.A.C. R18-2-726]

b. Opacity 
TV Renewal Permit No. 53399 Page 93 of 109 May 31, 2012 

APS-Cholla Generating Station 

The Permittee shall not cause, allow or permit visible emissions from 

sandblasting or other abrasive blasting operations in excess of 20% 

opacity, as measured by EPA Reference Method 9. [A.A.C. R18-2-702.B] 

2. Monitoring and Recordkeeping Requirement 

Each time an abrasive blasting project is conducted, the Permittee shall log in 

indelible ink or in an electronic format, a record of the following: 

a. The date the project was conducted; 

b. The duration of the project; and 

c. Type of control measures employed. 

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

3. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with 

A.A.C. R18-2-726 and A.A.C. R18-2-702.B. 

[A.A.C.R18-2-325] 

B. Use of Paints

1. Volatile Organic Compounds 

a. Emission Limitations/Standards 

While performing spray painting operations, the Permittee shall comply 

with the following requirements:

i. 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] 

ii. The Permittee or their designated contractor shall not either: 

(1) Employ, apply, evaporate, or dry any architectural 

coating containing photochemically reactive solvents for 

industrial or commercial purposes; or 

(2) Thin or dilute any architectural coating with a 

photochemically reactive solvent. 

[A.A.C.R18-2-727.B] 

iii. For the purposes of Condition XII.B.1.a.ii, 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 Conditions XII.B.1.a.iii.(1) through 

XII.B.1.a.iii(3) below, or which exceeds any of the following 

percentage composition limitations, referred to the total volume 

of solvent: 
TV Renewal Permit No. 53399 Page 94 of 109 May 31, 2012 

APS-Cholla Generating Station 

(1) A combination of the following types of compounds 

having an olefinic or cyclo-olefinic type of unsaturationhydrocarbons, alcohols, aldehydes, esters, ethers, or 

ketones: 5 percent. 

(2) A combination of aromatic compounds with eight or 

more carbon atoms to the molecule except ethylbenzene: 

8 percent. 

(3) A combination of ethylbenzene, ketones having 

branched hydrocarbon structures, trichloroethylene or 

toluene: 20 percent. 

[A.A.C.R18-2-727.C] 

iv. 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 of organic compounds described in 

Conditions XII.B.1.a.iii.(1) through XII.B.1.a.iii(3) above, 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] 

b. Monitoring and Recordkeeping Requirements 

i Each time a spray painting project is conducted, the Permittee 

shall log in indelible ink, or in an electronic format, a record of 

the following: 

(1) The date the project was conducted; 

(2) The duration of the project; 

(3) Type of control measures employed; 

(4) Material Safety Data Sheets for all paints and solvents 

used in the project; and 

(5) The amount of paint consumed during the project. 

ii. Architectural coating and spot painting projects shall be exempt 

from the recordkeeping requirements of Condition XII.B.1.b.i 

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

c. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance 

with A.A.C.R18-2-727. [A.A.C.R18-2-325] 

2. Opacity 

a. Emission Limitation/Standard 

The Permittee shall not cause, allow or permit visible emissions from 

painting operations in excess of 20% opacity, as measured by EPA 

Reference Method 9. [A.A.C. R18-2-702.B]
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APS-Cholla Generating Station 

b. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance 

with A.A.C. R18-2-702.B. [A.A.C. R18-2-325] 

C. Demolition/Renovation - Hazardous Air Pollutants

1. Emission Limitation/Standard 

The Permittee shall comply with all of the requirements of 40 CFR 61 Subpart M 

(National Emissions Standards for Hazardous Air Pollutants - Asbestos). 

[A.A.C. R18-2-1101.A.8] 

2. Monitoring and Recordkeeping Requirement 

The Permittee shall keep all required records in a file. The required records shall 

include the “NESHAP Notification for Renovation and Demolition Activities” 

form and all supporting documents. [A.A.C. R18-2-306.A.3.c] 

3. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with 

A.A.C. R18-2-1101.A.8. [A.A.C. R18-2-325] 

D. Solvent Degreasing 

1. 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] 

2. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with 

A.A.C. R18-2-730.F. [A.A.C. R18-2-325] 

E. Nonvehicle Air Conditioner Maintenance and/or Services 

1. The Permittee shall comply with the applicable requirements of 40 CFR 82 - 

Subpart F (Protection of Stratospheric Ozone - Recycling and Emissions 

Reduction). [40 CFR 82, Subpart F] 

2. The Permittee shall keep a record of all relevant paperwork to the applicable 

requirements of 40 CFR 82 - Subpart F on file. [A.A.C. R18-2-306.A.3.c] 

3. Permit Shield 

Compliance with the conditions of this Part shall be deemed compliance with 

A.A.C. R18-2-1101.A.8. [A.A.C. R18-2-325] 
TV Renewal Permit No. 53399 Page 96 of 109 May 31, 2012 

APS-Cholla Generating Station 

XIII. INTERNAL COMBUSTION ENGINES 

A. Applicability 

This Section applies to the following internal combustion engines as described in the 

equipment list in Attachment “C” of this permit. 

B. Particulate Matter and Opacity 

1. Emission Limits/Standards 

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

atmosphere from the internal combustion engines any smoke for any 

period greater than 10 consecutive seconds which exceeds 40% opacity. 

Visible emissions when starting cold equipment shall be exempt from 

this requirement for the first 10 minutes. [A.A.C. R18-2-719.E] 

b. The Permittee shall not cause, allow or permit the emission of particulate 

matter, caused by combustion of fuel, from the internal combustion 

engines having a heat input rate of 4200 million Btu per hour or less, in 

excess of the amounts calculated by the following equation: 

 [A.A.C. R18-2-719.C.1]

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. 

c. For the purposes of Condition XIII.B.1.b above, the heat input shall be 

the aggregate heat content of all fuels whose products of combustion 

pass through a stack or other outlet. Compliance tests shall be conducted 

during operation at the normal rated capacity of each unit. The total heat 

input of all operation generators and internal combustion engines 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] 

2. Monitoring, Recordkeeping and Reporting Requirements 

The Permittee shall conduct a weekly Visible Emissions Observation Procedure 

consistent with Condition I.H of this Attachment, for any visible emissions 

emanating from all internal combustion engines subject to this Section. 

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

C. Sulfur Dioxide 

1. Emission Limits/Standards 

a. The Permittee shall only burn low sulfur fuel oil in the internal

combustion engines located at the facility. Low sulfur oil is defined as 

fuel oil containing less than 0.90% by weight of sulfur. [A.A.C.R18-2-719.H] 

b. The Permittee shall not emit or cause to be emitted into the atmosphere 

any gases containing sulfur dioxide in excess of 1.0 pound per million 
TV Renewal Permit No. 53399 Page 97 of 109 May 31, 2012 

APS-Cholla Generating Station 

Btu heat input when low sulfur fuel oil is fired. [A.A.C.R18-2-719.F] 

2. Monitoring, Recordkeeping and Reporting Requirements 

a. The Permittee shall maintain records of the 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 lower heating value of the fuel. [A.A.C. R18-2-306.A.3.c and 

A.A.C. R18-2-719.I] 

b. 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%. 

[A.A.C. R18-2-719.J and 306.A.3] 

D. Permit Shield 

Compliance with the conditions of this Section shall be deemed compliance with A.A.C. 

R18-2-719.B, A.A.C. R18-2-719.C.1, A.A.C. R18-2-719.E, A.A.C. R18-2-719.F, A.A.C. 

R18-2-719.H, A.A.C. R18-2-719.I, and A.A.C. R18-2-719.J. [A.A.C. R18-2-325] 

XIV. MERCURY REQUIREMENTS 

A. Applicability 

 1. The requirements in this section are state enforceable only. 

 [Consent Order #A-19-09] 

2. The State Standards of Performance for Mercury Emissions from Coal-Fired 

Electric Steam Generating Units set forth in A.A.C. R18-2-734 shall not be 

enforceable until December 31, 2016. 

B. Operation and Maintenance (O&M) Plan 

 The Permittee shall implement the following Operation and Maintenance (O&M) plan, 

designed to achieve a minimum of 50 percent reduction of total inlet mercury where 

“inlet mercury” means the average concentration of mercury in coal burned at the facility, 

as determined by ASTM methods, EPA approved methods or an alternative method 

approved by the Director. 

1. The PM emissions CAM plan outlined in Attachment “E” of Permit No. 53399 

shall serve as the operation and maintenance plan for the fabric filters for 

reduction of mercury emissions from Units 1, 3 and 4, and from Unit 2 after 

installation of the fabric filter system. 

2. The Permittee shall annually inspect and maintain the fabric filter control devices 

in accordance with manufacturer’s specifications. 

3. The Permittee shall operate and maintain at all times the lime slurry flue gas 

desulfurization system on Units 1, 3 and 4, and on Unit 2 after the FGD is 

operational in a manner consistent with good air pollution control practice for 

minimizing mercury emissions. [A.A.C. R18-2-306.A.3.c and -331.A.3.e] 

 [Material permit conditions are indicated by underline and italics]

C. Monitoring, Recordkeeping, and Reporting Requirements [A.A.C. R18-2-306.A.3.c]

1. The Permittee shall analyze a representative sample from each train load of coal 
TV Renewal Permit No. 53399 Page 98 of 109 May 31, 2012 

APS-Cholla Generating Station 

delivered to the facility, and shall calculate average monthly mercury 

concentration in coal in parts per billion (ppb). Based on this analysis and the 

total amount of coal fired in Units 1, 2, 3 and 4, the Permittee shall determine 

pounds of inlet mercury for each unit every month (“Hg in”). 

2. The Permittee shall install, calibrate, operate and maintain continuous emission 

monitoring system (CEMS) for mercury on Unit 4 in accordance with vendor 

specifications. [A.A.C. R18-2-306.A.3.c and -331.A.3.c] 

 [Material permit conditions are indicated by underline and italics] 

3. The Permittee shall determine the mercury emissions in the exhaust of Unit 4 

boiler in pounds per GWHr, using the compliance-certified CEMS DAHS. The 

data shall be averaged on a monthly basis and recorded. Based on this analysis 

and monthly gross megawatt output recorded by the CEMS for each Unit, the 

Permittee shall determine pounds of mercury in exhaust for Units 1, 3 and 4 

every month and every month on Unit 2 after the fabric filter is operational (“Hg 

out”). 

4. As an option to the mercury CEMS, the Permittee may install and maintain a 

mercury sorbent trap system in the Unit 4 stack in accordance with vendor 

specifications. If a mercury sorbent trap system is used, the Permittee shall meet 

all of the following: 

a. Sample the stack gas at a rate proportional to the stack gas volumetric 

flow rate. The Permittee shall by using the sample volume measured by 

the gas meter and the results of the analyses of the sorbent traps, 

determine the average mercury concentration in the stack in micrograms 

per dry standard cubic meter. 

b. Analyze the sorbent traps on-site or at a qualified off-site laboratory 

using a desorption analyzer. When an appropriate protocol is provided 

by US EPA, the Permittee shall calibrate the analyzer by using National 

Institute of Standards and Technology (NIST) traceable mercury 

standards. 

c. On monthly basis, the Permittee shall determine the pounds of mercury 

in the exhaust of Units 1, 3, and 4, and in the exhaust of the Unit 2 after 

the fabric filter system becomes operational. 

5. At the end of each calendar year, the Permittee shall calculate and record the 

average calendar year mercury removal percentage based on the results of 

Conditions XIV.C.1 and XIV.C.3. Until such time that a fabric filter system is 

operational on Unit 2, mercury removal for Unit 2 shall be considered as zero. 

Annual mercury removal efficiency 

 = (Σ “Hg in” for Units 1, 3, 4 – Σ “Hg out” for Units 1, 3, 4) * 100 

 Σ “Hg in” for Units 1- 4 

D. Significant Permit Revision Application Submittal 

 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. The application shall include the 

following elements: [Consent Order #A-19-09]
TV Renewal Permit No. 53399 Page 99 of 109 May 31, 2012 

APS-Cholla Generating Station 

1. 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. 

2. 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. 

3. 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. 

4. 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; 

(a) 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. 

 (b) The exception in A.A.C. R18-2-734(G) shall not apply.
ATTACHMENT “C”: EQUIPMENT LIST

AIR QUALITY CONTROL PERMIT NO. 53399

FOR 

ARIZONA PUBLIC SERVICE COMPANY–CHOLLA GENERATING STATION 

Table C-1: Equipment List 

Equipment Operating 

Scenario Quantity Manufacturer Model/ Type 

Serial 

Number 

Date 

Installed Rated Capacity 

UNIT 1 

Boiler -

Tangential fired 

furnace 

Normal 1 Combustion 

Engineering R 19537 1961 

865K lbs/hr steam flow @1925 

psig @1005 degrees F at 

superheater outlet 

Coal Mills - bowl 

mills Normal 4 Combustion Engineering #633 

60814 

through 

60817 

1961 34,000 lbs/hr coal each 

Absorber – Lime 

slurry Normal 2 URS Tray Tower 2007 240,000 acfm each with combined 90% SO2 removal 

Fabric Filter Normal 1 Alstom Pulse Jet 2007 99.9% design efficiency 

UNIT 2

Boiler - 

Tangential fired 

furnace 

Normal 1 Combustion 

Engineering RR 7072 1974 

2,015K lbs/hr steam @1990 psig 

@1005 degrees F at superheater 

outlet 

Coal Mills - bowl 

mills Normal 5 Combustion Engineering #863 

72806 

through 

72810 

1974 94,400 lbs/hr coal each 

Scrubber/Absorbe

r Normal 

4 wet 

Venturi 

scrubber 

modules 

and 4 

absorber 

towers 

Research Cottrell -- -- 1974 413,500 acfm each with combined 

90% SO2 and 98% PM removal. 

Mechanical dust 

collector Normal 1 Zurn -- -- 1974 Approx. 70% efficiency @ 248,000- 332,000 lbs/hr gas flow. 

Emergency 

Diesel Generator Normal 1 Beloit Power 

Systems -- 604588-

R1 1974 750 KW @ 480 volts 

UNIT 3 

Boiler - 

Tangential fired 

furnace 

Normal 1 Combustion 

Engineering RR 9272 1975 

2,015K lbs/hr steam @1990 psig 

@1005 degrees F at superheater 

outlet 

Coal Mills - bowl 

mills Normal 5 Combustion Engineering #863 

74817 

through 

74821 

1975 94,400 lbs/hr coal each 

Absorber – Lime 

slurry Normal 1 BPE1 Tray Tower 2009 0.15 lbs/MMBtu design outlet emissions rate 

Fabric Filter Normal 1 Hamon Research 

Cottrell Pulse Jet 2009 99.9% design efficiency 

Emergency 

Diesel Generator Normal 1 Beloit Power 

Systems -- 504588-

R2 1975 750 KW @ 480 volts 

Cooling tower Normal 1 Marley 

6516-3-6 

forced 

draft-7 

cells 

-- 1975 140,000 gpm water flow 

UNIT 4 

Boiler - 

Tangential fired 

furnace 

Normal 1 Combustion 

Engineering RR 5174 1978 

2,830K lbs/hr steam @1990 psig 

@1005 degrees F at superheater 

outlet 

Coal Mills - bowl 

mills Normal 5 Combustion Engineering #903 

74840 

through 

74844 

1978 108,000 lbs/hr coal each 

TV Renewal Permit No. 53399 Page 100 of 109 March 28, 2012 

APS – Cholla Generating Station 
APS – Cholla Generating Station 

Equipment Operating 

Scenario Quantity Manufacturer Model/ Type 

Serial 

Number 

Date 

Installed Rated Capacity 

Absorber – Lime 

slurry Normal 1 BPE1 Tray Tower 2008 0.15 lbs/MMBtu design outlet emissions rate 

Fabric Filter Normal 1 Hamon Research 

Cottrell Pulse Jet 2008 99.9% design efficiency 

Emergency 

Diesel Generator Normal 1 Beloit Power 

Systems -- 504637-

R1 1978 900 KW @ 480 volts 

Cooling tower Normal 1 Marley 

6516-3-6 

Forced 

draft 11 

cells 

-- 1978 145,000 gpm water flow 

FLY ASH HANDLING SYSTEM 

Fly ash Baghouse Normal 2 GE GE-154-

6-12P -- 1988 

100% capacity pulse-jet baghouse, 

154 bags per baghouse, 6"x12' 

bags 

LIME SLAKING SYSTEM 

Old & New Lime 

Silo Baghouse Normal 1 Flex-Kleen 58 BVBS 

25IIG W33793 1994 25 bags, pulse jet baghouse, 6"x6' 

bags 

Old & New Lime 

Slaker Vent Wet 

Scrubber 

Normal 1 Ducon UW-4 IV 

size 30 -- 1994 2500 inlet acfm @200 degree F 

COAL WETTING SYSTEM 

Coal Dust 

Suppression 

System 

Normal 1 Nalco Nalco # -- 1995 

Chemical treatment and/or wetting 

at each crusher and various 

transfer points as needed. 

COAL HANDLING SYSTEM- NEW TRACK (New Source Performance Standards – Subpart Y Applicable) 

NU1 – Rail Car 

Discharge Point Normal 1 Continental Conveyor -- -- 

1974 

Retrofitte

d in 2008 

2,200 

NU2 – Conveyor 

12A Discharge Normal 1 Continental Conveyor -- -- 

1974 

Retrofitte

d in 2008 

2,200 

NU3 – Conveyor 

12B Discharge Normal 1 Continental Conveyor -- -- 

1974 

Retrofitte

d in 2008 

2,200 

NU4 - Crusher 

Tower #2 

Discharge To 

Conveyor 32 

North/South 

Normal 1 Continental 

Conveyor -- -- 

1974 

Retrofitte

d in 2008 

2,200 

NU5 – Crusher 

Tower #2 

Discharge To 

Conveyor 35 

Normal 1 Continental 

Conveyor -- -- 1974 560 

NU6 – Conveyor 

32 North/South 

Discharge 

Normal 1 Continental 

Conveyor -- -- 

1974 

Retrofitte

d in 2008 

2,200 

NU7- Transfer 

Tower #3 

Discharge To 

Conveyor 22 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

NU8 – Transfer 

Tower #3 

Discharge To 

Conveyor 33 

East/West 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

NU9 – Conveyor 

22 Discharge to 

Storage Pile 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

COAL UNLOADING SYSTEM – OLD TRACK –(A.A.C. Rules Applicable) 

TV Renewal Permit No. 53399 Page 101 of 109 March 28, 2012 
APS – Cholla Generating Station 

Equipment Operating 

Scenario Quantity Manufacturer Model/ Type 

Serial 

Number 

Date 

Installed Rated Capacity 

O1 – Old Track 

Unloading 

Hopper 

Inlet/Discharge 

Normal 2 Continental 

Conveyor -- -- 1961 560 

O2 – Conveyor 

11 Discharge To 

Crusher Tower #1 

Normal 1 Continental 

Conveyor -- -- 1961 560 

O3- Conveyor 11 

Discharge To 

Conveyor 21 

Normal 1 Continental 

Conveyor -- -- 1961 560 

O4 – Crusher 

Tower #1 

Discharge To 

Conveyor 31 

Normal 1 Continental 

Conveyor -- -- 1961 560 

O5 – Crusher 

Tower #1 

Discharge To 

Conveyor 35 

Normal 1 Continental 

Conveyor -- -- 1961 560 

O6 – Conveyor 

21 Discharge to 

Storage Pile 

Normal 1 Continental 

Conveyor -- -- 1961 560 

COAL RECLAIM SYSTEM 

RC1 – Reclaim 

Hopper Discharge Normal 1 Continental Conveyor -- -- 1974 1,800 

RC2 – Conveyor 

24 (E&W) 

Discharge To 

Conveyor 25 

(E&W) 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

R3 – Conveyor 

25 (E&W) 

Discharge To 

Crusher Tower #2 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

R4 – Crusher 

Tower #2 

Discharge To 

Conveyor 35 

Normal 1 Continental 

Conveyor -- -- 1974 560 

RC5 – Crusher 

Tower #2 

Discharge To 

Conveyor 32 

North/South 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

RC6 – Conveyor 

32 North/South 

Discharge To 

Transfer Tower 

#3 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

RC7 – Transfer 

Tower #3 

Discharge To 

Conveyor 33 

East/West 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

COAL SILO FEED SYSTEM 

CF1 – Conveyor 

31 Discharge Normal 1 Continental Conveyor -- -- 1961 560 

CF2 – Conveyor 

41 (A or B) 

Discharge 

Normal 1 Continental 

Conveyor -- -- 1974 560 

CF4 – Conveyor 

33 East/West 

Discharge To 

Conveyor 34 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

TV Renewal Permit No. 53399 Page 102 of 109 March 28, 2012 
APS – Cholla Generating Station 

Equipment Operating 

Scenario Quantity Manufacturer Model/ Type 

Serial 

Number 

Date 

Installed Rated Capacity 

North/South 

CF5 – Conveyor 

34 North/South 

Discharge To 

Conveyor 42 

(A&B) 

Normal 1 Continental 

Conveyor -- -- 1974 1,800 

CF6 – Conveyor 

34 North/South 

Discharge To 

Conveyor 43 

(A&B) 

Normal 1 Continental 

Conveyor -- -- 1975 1,800 

CF7 – Conveyor 

34 North/South 

Discharge To 

Conveyor 36 

(North & South) 

Normal 1 Continental 

Conveyor -- -- 1978 1,800 

CF8 – Conveyor 

36 (North & 

South) Discharge 

to Conveyor 44 

(A&B) 

Normal 1 Continental 

Conveyor -- -- 1978 1,800 

Dust Collector 

(Unit 1 Silo 

Ventilation & 

Conveyors, Tag 

no. DC-01A) 

Normal 1 MAC Equipment 

144MCF1

53-145, 

Style III 

36307-

001-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 12,350 

cfm; Static Pressure: 13.00” wg 

Dust Collector 

(Unit 2 Silo 

Ventilation, Tag 

no. DC-02A) 

Normal 1 MAC Equipment 

144MCF2

55-165, 

Style III 

36307-

031-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 14,000 

cfm; Static Pressure: 13.00” wg 

Dust Collector 

(Unit 2 Transfer 

Conveyors, Tag 

no. DC-02B) 

Normal 1 MAC Equipment 

144MCF3

61-85, 

Style III 

36307-

051-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 24,000 

cfm; Static Pressure: 14.00” wg 

Dust Collector 

(Unit 3 Silo 

Ventilation, Tag 

no. DC-03A) 

Normal 1 MAC Equipment 

144MCF1

53-145, 

Style III 

36307-

011-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 14,000 

cfm; Static Pressure: 13.00” wg 

Dust Collector 

(Unit 3 Transfer 

Conveyors, Tag 

no. DC-03B) 

Normal 1 MAC Equipment 

144MCF2

55-165, 

Style III 

36307-

041-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 12,000 

cfm; Static Pressure: 14.00” wg 

Dust Collector 

(Unit 4 Silo 

Ventilation, Tag 

no. DC-04A) 

Normal 1 MAC Equipment 

144MCF1

53-130, 

Style III 

36307-

061-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 11,000 

cfm; Static Pressure: 11.00” wg 

Dust Collector 

(Unit 4 Transfer 

Conveyors, Tag 

no. DC-04B) 

Normal 1 MAC Equipment 

144MCF1

53-145, 

Style III 

36307-

021-1 2002 

Exhaust Fan 

Volumetric Flow Rate: 12,000 

cfm; Static Pressure: 13.00” wg 

Crusher Tower 

Dust Collector Normal 1 MAC Equipment 

144MCF4

94-430, 

Style III 

118043-

001-1 2008 

Exhaust Fan 

Volumetric Flow Rate: 36,450 

cfm; Static Pressure: 13.00” wg 

Transfer Tower 

Dust Collector Normal 1 MAC Equipment 

144MCF2

55-200, 

Style III 

118043-

003-1 2008 

Exhaust Fan 

Volumetric Flow Rate: 17,600 

cfm; Static Pressure: 13.00” wg 

TV Renewal Permit No. 53399 Page 103 of 109 March 28, 2012 
TV Renewal Permit No. 53399 Page 104 of 109 March 28, 2012 

APS – Cholla Generating Station 

Table C-2: Stack Parameters 

Identification Stack 1 Stack 2 Stack 3 Stack 4 

Description Round Vertical Stack Round Vertical Stack Round Vertical 

Stack

Round Vertical 

Stack

Building Dimensions 

(boiler structure) 

50 ft W100 ft L155 ft 

H 

100 ft W100 ft L217 

ft H 

100 ft W100 ft 

L217 ft H 

120 ft W100 ft 

L247 ft H 

Height 250 ft 550 ft 550 ft 550 ft 

Inside Dimensions 11.25 ft 14.67 ft 17.15 ft 19.17 ft 

Exit Gas Temperature 123 oF 170.8 oF 127 oF 127 oF 

Exit Gas Velocity 48.74 ft/sec 68.0 ft/sec 63.23 ft/sec 74.59 ft/sec 

Table C-3: Continuous Emission Monitors 

Steam Unit NOx 

Monitor 

SO2 Monitor CO2 Monitor Opacity Monitor Flow Monitor CO 

Inlet: TML50 Inlet:TML20 

Steam Unit 1 TML 41 

Outlet: TML50 Outlet: TML20 

TML Lighthawk 

560 

TML Ultraflow 

150 

TML 

30U 

Inlet: TML50 Inlet:TML20 

Steam Unit 2 TML 41 

Outlet: TML50 Outlet: TML20 

Monitor Labs 

550M 

TML Ultraflow 

150 

TML 

30U 

Steam Unit 3 TML 41 TML50 TML20 TML Lighthawk 

560 

TML Ultraflow 

150 

TML 

30U 

Steam Unit 4 TML 41 TML50 TML20 TML Lighthawk 

560 

TML Ultraflow 

150 

TML 

30U 
Title V Renewal Permit # 53399 Page 105 of 109 May 31, 2012 

APS Cholla Generating Station 

ATTACHMENT "D": PHASE II ACID RAIN PROVISIONS

AIR QUALITY CONTROL PERMIT NO. 53399

FOR 

ARIZONA PUBLIC SERVICE COMPANY–CHOLLA GENERATING STATION 

I. 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”. 

II. SO2 ALLOWANCE†

 ALLOCATIONS AND NOx REQUIREMENTS FOR EACH AFFECTED UNIT 

 Units 2012 2013 2014 2015 2016 2017 2018 

Unit 1 2,034 2,034 2,034 2,034 2,034 2,034 2,034 

Unit 2 5,067 5,067 5,067 5,067 5,067 5,067 5,067 

Unit 3 4,858 4,858 4,858 4,858 4,858 4,858 4,858 

SO2 allowances under 

Tables 2, 3, or 4 of 40 

CFR part 73 

Unit 4 7,784 7,784 7,784 7,784 7,784 7,784 7,784 

NOx Emission Limit 

For each boiler Unit, NOx emission rate for each year, determined in accordance with 

40 CFR Part 75, shall not exceed the applicable emission limitation, under 40 CFR 

76.7(a)(1) of 0.40 lb/MMBtu for tangentially fired boilers. 

† As defined in 40 CFR §72.2, “Allowance” means an authorization by the Administrator under the Acid Rain 

Program to emit up to one ton of sulfur dioxide during or after a specified calendar year. 

III. COMMENTS, NOTES AND JUSTIFICATIONS 

APS has early-elected for NOx requirements on Units 1 through 4. 

IV. 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 Mr. 

James Riley on March 17, 2011. 
Title V Renewal Permit # 53399 Page 106 of 109 May 31, 2012 

APS Cholla Generating Station 

ATTACHMENT "E": COMPLIANCE ASSURANCE MONITORING 

AIR QUALITY CONTROL PERMIT NO. 53399

FOR 

ARIZONA PUBLIC SERVICE COMPANY–CHOLLA GENERATING STATION

I. APPLICABILITY 

The compliance assurance monitoring (CAM) required under this attachment shall apply to Steam Boiler 

Units 1 through 4 for particulate matter emissions. 

II. CAM PLAN 

A. Steam Boiler Units 

 1. Applicability 

 The CAM plan is applicable to Unit 1, 3, and 4 boilers and for Unit 2 boiler, upon the 

installation and operation of fabric filter control system. 

2. Indicator 

The opacity of exhaust gases shall be an indicator of particulate matter emissions. [40 CFR 64.6(c)(1)(i)] 

3. Monitoring Approach [40 CFR 64.6(c)(1)(i) and (ii)] 

a. The COMS installed on outlet duct work of the fabric filter baghouses serving the 

boiler units shall be used to monitor opacity for each stack. 

: 

b. Using COMS data, the Permittee shall calculate block 1-hour average opacities 

comprised of individual six minute averages excluding periods of boiler startup and 

shutdown. 

4. Excursion Determination 

Block 1-hour average opacities of 8% or greater shall be considered an excursion. For any 

such excursion event, the Permittee shall initiate a mandatory investigation within 30 

minutes, including inspection of the clean side of each in-service baghouse compartment for 

signs of dusting. If dusting is observed maintenance activities should be performed 

expeditiously. The Permittee shall keep records of the investigation conducted with details 

of any corrective action taken. [40 CFR 64.6(c)(2)] 

B. Steam Boiler Unit 2 

 1. Applicability 

 

 The section is applicable to Unit 2 until the fabric filter system is operational. 

2. Primary Indicators 

Until such time that the fabric filter system is operational on Unit 2, the flooded disc 
Title V Renewal Permit # 53399 Page 107 of 109 May 31, 2012 

APS Cholla Generating Station 

pressure drop (Δp) and slurry flow shall be primary indicators of Unit 2 Venturi scrubbers’ 

performance. [40 CFR 64.6(c)(1)(i)] 

2. Monitoring Approach [40 CFR 64.6(c)(1)(i) and (ii)] 

a. The Permittee shall measure the flooded disc Δp and slurry flow and collect four or 

more data points each hour. 

b. The measurement instruments in use for Δp and slurry flow shall be calibrated, 

maintained, and operated using procedures that take into account manufacturer’s 

recommendations. 

 3. Excursion Determination [40 CFR 64.6(c)(2)] 

a. Using the flooded disc Δp and slurry flow data, the Permittee shall calculate block 1-

hour Δp and slurry flow average excluding periods of boiler startup and shutdown. 

b. If at any point, excluding periods of boiler startup and shutdown, the block 1-hour 

Δp average is less than 15 inches of water column or the block 1-hour slurry flow 

average is equal to or less than 4,000 gallons per minute per pump, then an 

excursion has occurred and shall be recorded and reported accordingly. 

c. The Permittee shall also record the operational status of Unit 2 boiler (i.e. load 

change increase or decrease) in conjunction with the excursion recordation. 

III. CAM OPERATION REQUIREMENTS [40 CFR 64.7] 

A. Upon issuance of the permit, the Permittee shall conduct the monitoring for each affected control 

device in accordance with the CAM plan outlined in Section II of this attachment. 

E. At all times, the Permittee shall maintain the monitoring, including but not limited to, maintaining 

necessary parts for routine repairs of the monitoring equipment. 

F. Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance 

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

adjustments), the Permittee shall conduct all monitoring in continuous operation (or shall collect data 

at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data 

recorded during monitoring malfunctions, associated repairs, and required quality assurance or 

control activities shall not be used for purposes of this Section, including data averages and 

calculations, or fulfilling a minimum data availability requirement, if applicable. The Permittee shall 

use all the data collected during all other periods in assessing the operation of the control device and 

associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably 

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

part by poor maintenance or careless operation are not malfunctions. 

G. Upon detecting an excursion or exceedance, the Permittee shall restore operation of the pollutantspecific emissions unit (including the control device and associated capture system) to its normal or 

usual manner of operation as expeditiously as practicable in accordance with good air pollution 

control practices for minimizing emissions. The response shall include minimizing the period of any 

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

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

those caused by excused startup or shutdown conditions). Such actions may include initial 
Title V Renewal Permit # 53399 Page 108 of 109 May 31, 2012 

APS Cholla Generating Station 

inspection and evaluation, recording that operations returned to normal without operator action (such 

as through response by a computerized distribution control system), or any necessary follow-up 

actions to return operation to within the indicator range, designated condition, or below the 

applicable emission limitation or standard, as applicable. 

H. Determination of whether the Permittee has used acceptable procedures in response to an excursion

or exceedance will be based on information available, which may include but is not limited to, 

monitoring results, review of operation and maintenance procedures and records, and inspection of 

the control device, associated capture system, and the process. 

I. If the Permittee identifies a failure to achieve compliance with an emission limitation or standard for 

which the approved monitoring did not provide an indication of an excursion or exceedance while 

providing valid data, or the results of compliance or performance testing document a need to modify 

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

Director and, if necessary, submit a proposed modification to the permit to address the necessary 

monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator 

ranges or designated conditions, modifying the frequency of conducting monitoring and collecting 

data, or the monitoring of additional parameters. 

IV. QUALITY IMPROVEMENT PLAN (QIP) REQUIREMENTS [40 CFR 64.8] 

A. In the event that an accumulation of exceedances or excursions exceeds 5 percent duration of a 

pollutant-specific emissions unit's operating time for a reporting period based on the results of a 

determination made under Condition III.E above, the Permittee shall develop and implement a QIP. 

The Director may otherwise specify the threshold at a higher or lower percent or rely on other 

criteria for purposes of indicating whether a pollutant-specific emissions unit is being maintained and 

operated in a manner consistent with good air pollution control practices. 

B. The QIP shall include the following elements: 

1. The Permittee shall maintain a written QIP, if required, and have it available for inspection. 

2. The plan initially shall include procedures for evaluating the control performance problems 

and, based on the results of the evaluation procedures, the Permittee shall modify the plan to 

include procedures for conducting one or more of the following actions, as appropriate: 

a. Improved preventive maintenance practices; 

b. Process operation changes; 

c. Appropriate improvements to control methods; 

d. Other steps appropriate to correct control performance; 

e. More frequent or improved monitoring (only in conjunction with one or more steps a 

through d). 

C. If a QIP is required, the Permittee shall develop and implement a QIP as expeditiously as practicable 

and shall notify the Director if the period for completing the improvements contained in the QIP 

exceeds 180 days from the date on which the need to implement the QIP was determined. 

D. Following implementation of a QIP, upon any subsequent determination pursuant to Condition III.E 

above, the Director may require that the Permittee make reasonable changes to the QIP if the QIP is 

found to have: 
Title V Renewal Permit # 53399 Page 109 of 109 May 31, 2012 

APS Cholla Generating Station 

1. Failed to address the cause of the control device performance problems; or 

2. Failed to provide adequate procedures for correcting control device performance problems as 

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

minimizing emissions. 

E. Implementation of a QIP shall not excuse the Permittee from compliance with any existing emission 

limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement 

that may apply under federal, state, or local law, or any other applicable requirements under the Act. 

V. REPORTING AND RECORDKEEPING REQUIREMENTS [40 CFR 64.9] 

A. Upon issuance of the permit, the Permittee shall submit monitoring reports pertaining to this 

attachment to the Director along with Condition I.H, Attachment “B” and in accordance with Section 

XII, Attachment “A” of the permit. 

B. A report for monitoring under this attachment shall include, at a minimum, the information required 

under Condition I.H, Attachment “B” and Section XII, Attachment “A” of the permit, and the 

following information, as applicable: 

1. Summary information on the number, duration and cause (including unknown cause, if 

applicable) of excursions or exceedances, as applicable, and the corrective actions taken; 

2. Summary information on the number, duration and cause (including unknown cause, if 

applicable) for monitor downtime incidents (other than downtime associated with zero and 

span or other daily calibration checks, if applicable); and 

3. A description of the actions taken to implement a QIP during the reporting period as 

specified in Section IV above. Upon completion of a QIP, the Permittee shall include in the 

next summary report documentation that the implementation of the plan has been completed 

and reduced the likelihood of similar levels of excursions or exceedances occurring. 

4. The Permittee shall comply with the recordkeeping requirements specified in Section XIII, 

Attachment “A” of the permit. The Permittee shall maintain records of monitoring data, 

monitor performance data, corrective actions taken, any written quality improvement plan 

required pursuant to Section IV above and any activities undertaken to implement a quality 

improvement plan, and other supporting information required to be maintained under this 

section (such as data used to document the adequacy of monitoring, or records of monitoring 

maintenance or corrective actions). 

5. Instead of paper records, the Permittee may maintain records on alternative media, such as 

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such 

alternative media allows for expeditious inspection and review, and does not conflict with 

other applicable recordkeeping requirements. 

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

 Compliance with the terms of this attachment shall be deemed compliance with 40 CFR Part 64.