Department of 

Environmental Quality 

Amanda Smith 

Executive Director 

DIVISION OF AIR QUALITY 

Cheryl Heying 

Director 

10795

State of Utah 

GARY R. HERBERT 

Governor 

GREG BELL 

Lieutenant Governor

 

 

Title V Operating Permit 

PERMIT NUMBER: 4900018003 

DATE OF PERMIT: October 28, 2009

Date of Last Revision: October 28, 2009 

This Operating Permit is issued to, and applies to the following: 

Name of Permittee: 

 

Provo City Power 

Department of Energy 

251 West 800 North 

Provo UT 84601 

Permitted Location: 

Provo City Power: Power Plant 

702 North 300 West 

Provo UT 84601 

 UTM coordinates: 443,455 m Easting, 4,454,710 m Northing

 SIC code: 4911 (Electric Services) 

UTAH AIR QUALITY BOARD 

By: Prepared By: 

_________________________________ _____________________________ 

M. Cheryl Heying, Executive Secretary Robert Grandy 

150 North 1950 West • Salt Lake City, UT 

Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 

Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 

www.deq.utah.gov 

Printed on 100% recycled paper 
ENFORCEABLE DATES AND TIMELINES

The following dates or timeframes are referenced in 

Section I: General Provisions of this permit. 

Annual Certification Due: March 31, and on that date of every calendar year that this permit 

is in force. 

Renewal application due: April 28, 2014 

Permit expiration date: October 28, 2014 

Definition of “prompt”: written notification within 14 days. 

ABSTRACT

The Provo Downtown Power Plant is located in Provo, Utah County, Utah. The plant has five electric 

generators. Four dual fuel internal combustion engines and two natural gas boilers are used to power the 

generators. Each engine and boiler has a separate stack for the exhaust emissions. 

All generation units are best economic resource units for the Utah Municipal Power Agency (UMPA). 

The power production of the plant varies depending on weather conditions, rainfall, and economics of 

operation. An emergency generator has been installed to provide backup power to the iProvo headend facility. 

The Provo Downtown Power Plant is a major source of NOx and is subject to the Utah State Implementation 

Plan (SIP) IX.H.3.d. 

Project OPP0107950007 Page 2 Title V Operating Permit #4900018003 
OPERATING PERMIT HISTORY

 

Permit/Activity Date Issued Recorded Changes 

Title V renewal application 

(Project #OPP0107950007) 

Additions: 

-Renewal 

-Updated the Utah SIP citation (from IX.H.1.b.D to 

IX.H.3.d.) 

-Added maintenance condition from R307-401-8(2). 

Title V administrative 

amendment by DAQ 

(Project #OPP0107950005) 

2/22/2005 Changes: to incorporate conditions from new approval 

order issued to Provo City Power for new emergency 

generator. 

Title V renewal application 

(Project #OPP0107950004) 

5/22/2003 

Title V reopening for cause 

by DAQ (Project 

#OPP0107950003) 

7/14/1998 Changes: to modify Provision I.U.1 of the permit to 

reference the inventory rule directly. 

Title V administrative 

amendment by DAQ 

(Project #OPP0107950002) 

8/8/1997 Changes: The permit was modified to correct an error in 

the abstract and to correct the initial compliance 

certification date to 3/31/98. 

Title V initial application 

(Project #OPP0107950001) 

6/3/1997 

Project OPP0107950007 Page 3 Title V Operating Permit #4900018003 
Table of Contents

ENFORCEABLE DATES AND TIMELINES .............................................................................................. 2

ABSTRACT ...................................................................................................................................................... 2

OPERATING PERMIT HISTORY................................................................................................................ 3

SECTION I: GENERAL PROVISIONS........................................................................................................ 5

Federal Enforcement. ..................................................................................................................................... 5

Permitted Activity(ies). .................................................................................................................................. 5

Duty to Comply.............................................................................................................................................. 5

Permit Expiration and Renewal...................................................................................................................... 6

Application Shield.......................................................................................................................................... 6

Severability. ................................................................................................................................................... 6

Permit Fee. ..................................................................................................................................................... 6

No Property Rights......................................................................................................................................... 6

Revision Exception. ....................................................................................................................................... 6

Inspection and Entry. ..................................................................................................................................... 6

Certification.................................................................................................................................................... 7

Compliance Certification. .............................................................................................................................. 7

Permit Shield.................................................................................................................................................. 8

Emergency Provision. .................................................................................................................................... 8

Operational Flexibility. .................................................................................................................................. 9

Off-permit Changes........................................................................................................................................ 9

Administrative Permit Amendments.............................................................................................................. 9

Permit Modifications...................................................................................................................................... 9

Records and Reporting................................................................................................................................... 9

Reopening for Cause. ................................................................................................................................... 11

Inventory Requirements. .............................................................................................................................. 11

Title IV and Other, More Stringent Requirements....................................................................................... 11

SECTION II: SPECIAL PROVISIONS....................................................................................................... 12

Emission Unit(s) Permitted to Discharge Air Contaminants. ...................................................................... 12

Requirements and Limitations ..................................................................................................................... 12

Conditions on permitted source (Source-wide)........................................................................................................ 12

Conditions on Dual Fuel Internal Combustion Engines........................................................................................... 14

Conditions on Natural Gas Fired Boilers. ................................................................................................................ 17

Conditions on Emergency Generator....................................................................................................................... 19

Emissions Trading........................................................................................................................................ 20

Alternative Operating Scenarios .................................................................................................................. 20

SECTION III: PERMIT SHIELD ................................................................................................................ 20

SECTION IV: ACID RAIN PROVISIONS ................................................................................................. 20

This source is not subject to Title IV. This section is not applicable........................................................... 20

REVIEWER COMMENTS........................................................................................................................... 21

Project OPP0107950007 Page 4 Title V Operating Permit #4900018003 
Issued under authority of Utah Code Ann. Section 19-2-104 and 19-2-109.1, and in accordance with Utah 

Administrative Code R307-415 Operating Permit Requirements. 

 

All definitions, terms and abbreviations used in this permit conform to those used in Utah Administrative Code 

R307-101 and R307-415 (Rules), 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 Rules. 

Where a permit condition in Section I, General Provisions, partially recites or summarizes an applicable rule, the 

full text of the applicable portion of the rule shall govern interpretations of the requirements of the rule. In the 

case of a conflict between the Rules and the permit terms and conditions of Section II, Special Provisions, the 

permit terms and conditions of Section II shall govern except as noted in Provision I.M, Permit Shield. 

SECTION I: GENERAL PROVISIONS

 I.A Federal Enforcement. 

 All terms and conditions in this permit, including those provisions designed to limit the 

potential to emit, are enforceable by the EPA and citizens under the Clean Air Act of 1990 

(CAA) except those terms and conditions that are specifically designated as "State 

Requirements". (R307-415-6b) 

 I.B Permitted Activity(ies). 

 Except as provided in R307-415-7b(1), the permittee may not operate except in compliance 

with this permit. (See also Provision I.E, Application Shield) 

 I.C Duty to Comply. 

 I.C.1 The permittee must comply with all conditions of the operating permit. Any permit 

noncompliance constitutes a violation of the Air Conservation Act and is grounds for any of 

the following: enforcement action; permit termination; revocation and reissuance; 

modification; or denial of a permit renewal application. (R307-415-6a(6)(a)) 

 I.C.2 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. (R307-415-6a(6)(b)) 

 I.C.3 The permittee shall furnish to the Executive Secretary, within a reasonable time, any 

information that the Executive Secretary may request in writing to determine whether cause 

exists for modifying, revoking and reissuing, or terminating this permit or to determine 

compliance with this permit. Upon request, the permittee shall also furnish to the Executive 

Secretary copies of records required to be kept by this permit or, for information claimed to 

be confidential, the permittee may furnish such records directly to the EPA along with a 

claim of confidentiality. (R307-415-6a(6)(e)) 

 I.C.4 This permit may be modified, revoked, reopened, and reissued, or terminated for cause. 

The filing of a request by the permittee for a permit modification, revocation and 

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

noncompliance shall not stay any permit condition, except as provided under R307-415-

7f(1) for minor permit modifications. (R307-415-6a(6)(c)) 

Project OPP0107950007 Page 5 Title V Operating Permit #4900018003 
 I.D Permit Expiration and Renewal. 

 I.D.1 This permit is issued for a fixed term of five years and expires on the date shown under 

"Enforceable Dates and Timelines" at the front of this permit. (R307-415-6a(2)) 

 I.D.2 Application for renewal of this permit is due on or before the date shown under 

"Enforceable Dates and Timelines" at the front of this permit. An application may be 

submitted early for any reason. (R307-415-5a(1)(c)) 

 I.D.3 An application for renewal submitted after the due date listed in I.D.2 above shall be 

accepted for processing, but shall not be considered a timely application and shall not 

relieve the permittee of any enforcement actions resulting from submitting a late 

application. (R307-415-5a(5)) 

 I.D.4 Permit expiration terminates the permittee's right to operate unless a timely and complete 

renewal application is submitted consistent with R307-415-7b (see also Provision I.E, 

Application Shield) and R307-415-5a(1)(c) (see also Provision I.D.2). (R307-415-7c(2)) 

 I.E Application Shield. 

 If the permittee submits a timely and complete application for renewal, the permittee's 

failure to have an operating permit will not be a violation of R307-415, until the Executive 

Secretary takes final action on the permit renewal application. In such case, the terms and 

conditions of this permit shall remain in force until permit renewal or denial. This 

protection shall cease to apply if, subsequent to the completeness determination required 

pursuant to R307-415-7a(3), and as required by R307-415-5a(2), the applicant fails to 

submit by the deadline specified in writing by the Executive Secretary any additional 

information identified as being needed to process the application. (R307-415-7b(2)) 

 I.F Severability. 

 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. (R307-415-6a(5)) 

 I.G Permit Fee. 

 I.G.1 The permittee shall pay an annual emission fee to the Executive Secretary consistent with 

R307-415-9. (R307-415-6a(7)) 

 I.G.2 The emission fee shall be due on October 1 of each calendar year or 45 days after the source 

receives notice of the amount of the fee, whichever is later. (R307-415-9(4)(a)) 

 I.H No Property Rights. 

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

(R307-415-6a(6)(d)) 

 I.I Revision Exception. 

 No permit revision shall be required, under any approved economic incentives, marketable 

permits, emissions trading and other similar programs or processes for changes that are 

provided for in this permit. (R307-415-6a(8)) 

 I.J Inspection and Entry. 

Project OPP0107950007 Page 6 Title V Operating Permit #4900018003 
 I.J.1 Upon presentation of credentials and other documents as may be required by law, the 

permittee shall allow the Executive Secretary or an authorized representative to perform any 

of the following: 

 I.J.1.a Enter upon the permittee's premises where the source is located or emissions related activity 

is conducted, or where records are kept under the conditions of this permit. (R307-415-

6c(2)(a)) 

 I.J.1.b Have access to and copy, at reasonable times, any records that must be kept under the 

conditions of this permit. (R307-415-6c(2)(b)) 

 I.J.1.c Inspect at reasonable times any facilities, equipment (including monitoring and air pollution 

control equipment), practice, or operation regulated or required under this permit. (R307-

415-6c(2)(c)) 

 I.J.1.d Sample or monitor at reasonable times substances or parameters for the purpose of assuring 

compliance with this permit or applicable requirements. (R307-415-6c(2)(d)) 

 I.J.2 Any claims of confidentiality made on the information obtained during an inspection shall 

be made pursuant to Utah Code Ann. Section 19-1-306. (R307-415-6c(2)(e)) 

 I.K Certification. 

 Any application form, report, or compliance certification submitted pursuant to this permit 

shall contain certification as to its truth, accuracy, and completeness, by a responsible 

official as defined in R307-415-3. 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. (R307-415-5d) 

 I.L Compliance Certification. 

 I.L.1 Permittee shall submit to the Executive Secretary an annual compliance certification, 

certifying compliance with the terms and conditions contained in this permit, including 

emission limitations, standards, or work practices. This certification shall be submitted no 

later than the date shown under "Enforceable Dates and Timelines" at the front of this 

permit, and that date each year following until this permit expires. The certification shall 

include all the following (permittee may cross-reference this permit or previous reports): 

(R307-415-6c(5)) 

 I.L.1.a The identification of each term or condition of this permit that is the basis of the 

certification; 

 I.L.1.b The 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. Such 

methods and other means shall include, at a minimum, the monitoring and related 

recordkeeping and reporting requirements in this permit. If necessary, the permittee also 

shall identify any other material information that must be included in the certification to 

comply with section 113(c)(2) of the Act, which prohibits knowingly making a false 

certification or omitting material information; 

 I.L.1.c The status of compliance with the terms and conditions of the permit for the period covered 

by the certification, including whether compliance during the period was continuous or 

intermittent. The certification shall be based on the method or means designated in 

Project OPP0107950007 Page 7 Title V Operating Permit #4900018003 
Provision I.L.1.b. The certification shall identify each deviation and take it into account in 

the compliance certification. The certification shall also identify as possible exceptions to 

compliance any periods during which compliance is required and in which an excursion or 

exceedance as defined under 40 CFR Part 64 occurred; and 

 I.L.1.d Such other facts as the Executive Secretary may require to determine the compliance status. 

 I.L.2 The permittee shall also submit all compliance certifications to the EPA, Region VIII, at the 

following address or to such other address as may be required by the Executive Secretary: 

(R307-415-6c(5)(d)) 

Environmental Protection Agency, Region VIII 

Office of Enforcement, Compliance and Environmental Justice 

(mail code 8ENF) 

1595 Wynkoop Street 

Denver, CO 80202-1129 

 I.M Permit Shield. 

 I.M.1 Compliance with the provisions of this permit shall be deemed compliance with any 

applicable requirements as of the date of this permit, provided that: 

 I.M.1.a Such applicable requirements are included and are specifically identified in this permit, or 

(R307-415-6f(1)(a)) 

 I.M.1.b Those requirements not applicable to the source are specifically identified and listed in this 

permit. (R307-415-6f(1)(b)) 

 I.M.2 Nothing in this permit shall alter or affect any of the following: 

 I.M.2.a The emergency provisions of Utah Code Ann. Section 19-1-202 and Section 19-2-112, and 

the provisions of the CAA Section 303. (R307-415-6f(3)(a)) 

 I.M.2.b The liability of the owner or operator of the source for any violation of applicable 

requirements under Utah Code Ann. Section 19-2-107(2)(g) and Section 19-2-110 prior to 

or at the time of issuance of this permit. (R307-415-6f(3)(b) 

 I.M.2.c The applicable requirements of the Acid Rain Program, consistent with the CAA Section 

408(a). (R307-415-6f(3)(c)) 

 I.M.2.d The ability of the Executive Secretary to obtain information from the source under Utah 

Code Ann. Section 19-2-120, and the ability of the EPA to obtain information from the 

source under the CAA Section 114. (R307-415-6f(3)(d)) 

 I.N Emergency Provision. 

 I.N.1 An "emergency" is any situation arising from sudden and reasonably unforeseeable events 

beyond the control of the source, including acts of God, which situation requires immediate 

corrective action to restore normal operation, and that causes the source to exceed a 

technology-based emission limitation under this 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 preventive maintenance, 

careless or improper operation, or operator error. (R307-415-6g(1)) 

Project OPP0107950007 Page 8 Title V Operating Permit #4900018003 
 I.N.2 An emergency constitutes an affirmative defense to an action brought for noncompliance 

with such technology-based emission limitations if the affirmative defense is demonstrated 

through properly signed, contemporaneous operating logs, or other relevant evidence that: 

 I.N.2.a An emergency occurred and the permittee can identify the causes of the emergency. (R307-

415-6g(3)(a)) 

 I.N.2.b The permitted facility was at the time being properly operated. (R307-415-6g(3)(b)) 

 I.N.2.c During the period of the emergency the permittee took all reasonable steps to minimize 

levels of emissions that exceeded the emission standards, or other requirements in this 

permit. (R307-415-6g(3)(c)) 

 I.N.2.d The permittee submitted notice of the emergency to the Executive Secretary within two 

working days of the time when emission limitations were exceeded due to the emergency. 

This notice must contain a description of the emergency, any steps taken to mitigate 

emissions, and corrective actions taken. This notice fulfills the requirement of Provision 

I.S.2.c below. (R307-415-6g(3)(d)) 

 I.N.3 In any enforcement proceeding, the permittee seeking to establish the occurrence of an 

emergency has the burden of proof. (R307-415-6g(4)) 

 I.N.4 This emergency provision is in addition to any emergency or upset provision contained in 

any other section of this permit. (R307-415-6g(5)) 

 I.O Operational Flexibility. 

 Operational flexibility is governed by R307-415-7d(1). 

 I.P Off-permit Changes. 

 Off-permit changes are governed by R307-415-7d(2). 

 I.Q Administrative Permit Amendments. 

 Administrative permit amendments are governed by R307-415-7e. 

 I.R Permit Modifications. 

 Permit modifications are governed by R307-415-7f. 

 I.S Records and Reporting. 

 I.S.1 Records. 

 I.S.1.a The records of all required monitoring data and support information shall be retained by the 

permittee for a period of at least five years from the date of the monitoring sample, 

measurement, report, or application. Support information includes all calibration and 

maintenance records, all original strip-charts or appropriate recordings for continuous 

monitoring instrumentation, and copies of all reports required by this permit. (R307-415-

6a(3)(b)(ii)) 

 I.S.1.b For all monitoring requirements described in Section II, Special Provisions, the source shall 

record the following information, where applicable: (R307-415-6a(3)(b)(i)) 

Project OPP0107950007 Page 9 Title V Operating Permit #4900018003 
 I.S.1.b.1 The date, place as defined in this permit, and time of sampling or measurement. 

 I.S.1.b.2 The date analyses were performed. 

 I.S.1.b.3 The company or entity that performed the analyses. 

 I.S.1.b.4 The analytical techniques or methods used. 

 I.S.1.b.5 The results of such analyses. 

 I.S.1.b.6 The operating conditions as existing at the time of sampling or measurement. 

 I.S.1.c Additional record keeping requirements, if any, are described in Section II, Special 

Provisions. 

 I.S.2 Reports. 

 I.S.2.a Monitoring reports shall be submitted to the Executive Secretary every six months, or more 

frequently if specified in Section II. All instances of deviation from permit requirements 

shall be clearly identified in the reports. (R307-415-6a(3)(c)(i)) 

 I.S.2.b All reports submitted pursuant to Provision I.S.2.a shall be certified by a responsible official 

in accordance with Provision I.K of this permit. (R307-415-6a(3)(c)(i) 

 I.S.2.c The Executive Secretary shall be notified promptly of any deviations from permit 

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

probable cause of such deviations, and any corrective actions or preventative measures 

taken. Prompt, as used in this condition, shall be defined as written notification within the 

number of days shown under "Enforceable Dates and Timelines" at the front of this permit. 

Deviations from permit requirements due to unavoidable breakdowns shall be reported in 

accordance with the provisions of R307-107. (R307-415-6a(3)(c)(ii)) 

 I.S.3 Notification Addresses. 

 I.S.3.a All reports, notifications, or other submissions required by this permit to be submitted to the 

Executive Secretary are to be sent to the following address or to such other address as may 

be required by the Executive Secretary: 

Utah Division of Air Quality 

P.O. Box 144820 

Salt Lake City, UT 84114-4820 

Phone: 801-536-4000 

 I.S.3.b All reports, notifications or other submissions required by this permit to be submitted to the 

EPA should be sent to one of the following addresses or to such other address as may be 

required by the Executive Secretary: 

For annual compliance certifications: 

Environmental Protection Agency, Region VIII 

Office of Enforcement, Compliance and Environmental Justice 

(mail code 8ENF) 

1595 Wynkoop Street 

Project OPP0107950007 Page 10 Title V Operating Permit #4900018003 
Denver, CO 80202-1129 

For reports, notifications, or other correspondence related to permit modifications, 

applications, etc.: 

Environmental Protection Agency, Region VIII 

Office of Partnerships & Regulatory Assistance Air & Radiation Program (mail code 8PAR) 

1595 Wynkoop Street 

Denver, CO 80202-1129 

Phone: 303-312-6440 

 I.T Reopening for Cause. 

 I.T.1 A permit shall be reopened and revised under any of the following circumstances: 

 I.T.1.a New applicable requirements become applicable to the permittee and there is a remaining 

permit term of three or more years. No such reopening is required if the effective date of 

the requirement is later than the date on which this permit is due to expire, unless the terms 

and conditions of this permit have been extended pursuant to R307-415-7c(3), application 

shield. (R307-415-7g(1)(a)) 

 I.T.1.b The Executive Secretary or EPA determines that this permit contains a material mistake or 

that inaccurate statements were made in establishing the emissions standards or other terms 

or conditions of this permit. (R307-415-7g(1)(c)) 

 I.T.1.c EPA or the Executive Secretary determines that this permit must be revised or revoked to 

assure compliance with applicable requirements. (R307-415-7g(1)(d)) 

 I.T.1.d Additional applicable requirements are to become effective before the renewal date of this 

permit and are in conflict with existing permit conditions. (R307-415-7g(1)(e)) 

 I.T.2 Additional requirements, including excess emissions requirements, become applicable to a 

Title IV affected source under the Acid Rain Program. Upon approval by EPA, excess 

emissions offset plans shall be deemed to be incorporated into this permit. (R307-415-

7g(1)(b)) 

 I.T.3 Proceedings to reopen and issue a permit shall follow the same procedures as apply to initial 

permit issuance and shall affect only those parts of this permit for which cause to reopen 

exists. (R307-415-7g(2)) 

 I.U Inventory Requirements. 

 An emission inventory shall be submitted in accordance with the procedures of R307-150, 

Emission Inventories. (R307-150) 

 I.V Title IV and Other, More Stringent Requirements 

 Where an applicable requirement is more stringent than an applicable requirement of 

regulations promulgated under Title IV of the Act, Acid Deposition Control, both 

provisions shall be incorporated into this permit. (R307-415-6a(1)(b)) 

Project OPP0107950007 Page 11 Title V Operating Permit #4900018003 
SECTION II: SPECIAL PROVISIONS

 

II.A Emission Unit(s) Permitted to Discharge Air Contaminants.

(R307-415-4(3)(a) and R307-415-4(4)) 

II.A.1 Permitted Source 

Source-wide 

II.A.2 Natural Gas Fired Boilers 

Two (2) 9,200 kW boilers 

II.A.3 Dual Fuel Internal Combustion Engines 

Includes four (4) 2,585 kW engines 

II.A.4 Miscellaneous Emission Units 

Includes the following units: natural gas fired boiler (3.4 MMBtu/hr), 

two portable kerosene heaters (0.1 MMBtu/hr each), underground diesel storage tank 

(50,000 gallons), four diesel day tanks, diesel fuel pumps, three stoddard solvent parts 

washers No unit-specific applicable requirements. 

II.A.5 Emergency Generator 

Small diesel fuel generator for iProvo Headend facility. 

II.B Requirements and Limitations 

The following emission limitations, standards, and operational limitations apply to the permitted facility 

as indicated: 

II.B.1 Conditions on permitted source (Source-wide).

II.B.1.a Condition: 

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

practicable, maintain and operate any permitted plant equipment, including associated air pollution 

control equipment, in a manner consistent with good air pollution control practice for minimizing 

emissions. Determination of whether acceptable operating and maintenance procedures are being used 

will be based on information available to the Executive Secretary which may include, but is not limited 

to, monitoring results, opacity observations, review of operating and maintenance procedures, and 

inspection of the source. [Authority granted under R307-401-8(2); condition originated in DAQEAN0795006-04]. 

II.B.1.a.1 Monitoring: 

Records required for this permit condition will serve as monitoring. 

II.B.1.a.2 Recordkeeping: 

Records documenting scheduled and unscheduled maintenance shall be maintained. A copy of all 

manufacturers' instructions, established operating instructions, or established maintenance 

practices for pollution control equipment and pollution emitting equipment shall be made 

available upon request. 

Project OPP0107950007 Page 12 Title V Operating Permit #4900018003 
II.B.1.a.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.1.b Condition: 

Emissions of NOx shall be no greater than 254 tons per rolling 12-month period for Unit Engines and Unit 

Boilers combined. [Authority granted under Utah SIP IX.H.3.d and R307-401-8(1)(a) [BACT]; condition 

originated in DAQE-AN0795006-04]. 

II.B.1.b.1 Monitoring: 

Compliance with the emission limitation shall be determined by the following equation: 

Emissions (tons/rolling 12-month period) = (Power production in kW-hrs/rolling 12-month 

period) x (Emission factor in grams/kW-hr) x (1 lb/453.59 g) x (1ton/2000 lbs) 

The emission factors for NOx shall be derived from the most recent emission test results. 

Emission testing frequency shall follow schedule found in Conditions II.B.2.a and II.B.3.a. 

NOx emissions shall be the sum of emissions from each engine and boiler. Power production 

shall be determined on a rolling 12-month total. Within the first 10 days of each month a new 12-

month total shall be calculated using data from the previous 12 months. 

II.B.1.b.2 Recordkeeping: 

The number of kilowatt hours generated by each engine and boiler shall be recorded on a monthly 

basis. 

Results shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.1.b.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.1.c Condition: 

Emissions of NOx shall be no greater than 2.45 tons per day for Unit Engines and Unit Boilers combined. 

[Authority granted under Utah SIP IX.H.3.d and R307-401-8(1)(a) [BACT]; condition originated in 

DAQE-AN0795006-04]. 

II.B.1.c.1 Monitoring: 

Compliance with the emission limitation shall be determined by the following equation: 

Emissions (tons/day) = (Power production in kW-hrs/day) x (Emission factor in grams/kW-hr) x 

(1 lb/453.59 g) x (1 ton/2000 lbs) 

The emission factors for NOx shall be derived from the most recent emission test results. 

Emission testing frequency shall follow schedule found in Conditions II.B.2.a and II.B.3.a. 

NOx emissions shall be the sum of emissions from each engine and boiler. Power production and 

Project OPP0107950007 Page 13 Title V Operating Permit #4900018003 
emissions from each engine and boiler shall be determined daily. 

II.B.1.c.2 Recordkeeping: 

The number of kilowatt hours generated by each engine and boiler shall be recorded on a daily 

basis. 

Results shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.1.c.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.1.d Condition: 

If plantwide NOx emissions from the engines exceed 200 tons per rolling 12-month period, the permittee 

shall submit a plan to install continuous emission monitoring systems (CEM) for Nox on each stack. The 

plan shall propose specifications for the installation, calibration and maintenance of a CEM. The CEM 

shall be on line within 12 months following the approval of the plan. [Authority granted under R307-401-

8(1)(a) (BACT); condition originated in DAQE-AN0795006-04]. 

II.B.1.d.1 Monitoring: 

NOx emissions shall be determined by the following equation: 

Emissions (tons/rolling 12-month period) = (Power production in kW-hrs/rolling 12-month 

period) x (Emission factor in grams/kW-hr) x (1 lb/453.59 g) x (1 ton/2000 lbs) 

The number of kilowatt hours generated by each engine and boiler shall be recorded on a monthly 

basis. The emission factors for NOx shall be derived from the most recent emission test results. 

NOx emissions shall be the sum of emissions from each engine and boiler. Each month, a new 12-

month total shall be calculated using data from the previous 12 months. 

II.B.1.d.2 Recordkeeping: 

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.1.d.3 Reporting: 

The permittee shall submit a report of the emissions to the Executive Secretary within 30 days of 

determining that NOx emissions exceeded 200 tons over the previous 12 months. Within 90 days 

of such determination, the permittee shall 

submit to the Executive Secretary for approval of the CEM installation plan. 

II.B.2 Conditions on Dual Fuel Internal Combustion Engines.

II.B.2.a Condition: 

Emissions of NOx shall be no greater than 10.4 g/kW-hr and 1,660 ppmdv for each engine. [Authority 

granted under Utah SIP IX.H.3.d and R307-401-8(1)(a) [BACT]; condition originated in DAQEAN0795006-04]. 

Project OPP0107950007 Page 14 Title V Operating Permit #4900018003 
II.B.2.a.1 Monitoring: 

Stack testing shall be performed as specified here: 

(a) Frequency. The engine shall be tested every 8,760 hours of operation and/or at least every five 

years based on the date of the last stack test. 

(b) Notification. At least 30 days before the test, the source shall notify the Executive Secretary 

of the date, time, and place of testing and provide a copy of the test protocol. The source shall 

attend a pretest conference if determined 

necessary by the Executive Secretary. 

(c) The emission sample point shall be designed to conform to the requirements of 40 CFR 60, 

Appendix A, Method 1. In addition, Occupational Safety and Health Administration (OSHA) 

approved access shall be provided to the test location. (R307-165-2) 

(d) Methods to be used: 

 (1) To determine stack volumetric flow rate - 40 CFR 60, Appendix A, Method 2. 

 (2) To test for NOx emissions - 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, 

 or 7E. 

(e) Calculations. To determine mass emission rates (g/kW-hr) the pollutant concentration as 

determined by the appropriate methods above shall be multiplied by the volumetric flow rate, 

divided by the engine's power output during the test and multiplied by any necessary conversion 

factors. 

(f) Production Rate During Testing. The production rate during all compliance testing shall be no 

less than 90% of the maximum production achieved in the previous three (3) years. (R307-165-

3). 

II.B.2.a.2 Recordkeeping: 

Results of all monitoring shall be recorded and maintained in accordance with the associated test 

method and Provision S.1 in Section I of this permit. 

II.B.2.a.3 Reporting: 

Results of required stack testing shall be submitted to the Executive Secretary within 30 days of 

completion of the testing. The submittal shall clearly identify results and indicate compliance 

status. The annual compliance certification required by Provision L in Section I of this permit 

shall use the most recent test results as a basis for stating compliance status for this limitation. 

Project OPP0107950007 Page 15 Title V Operating Permit #4900018003 
II.B.2.b Condition: 

The permittee shall use natural gas as the primary fuel in all of the dual fuel engines. Distillate fuel oil #1 

or #2, or a combination of #1 and #2, may be used only during a 15-minute start-up and 15 minutes shutdown period; backup fuel during periods of natural gas curtailment; for maintenance firings; for break in 

firing; system electrical power outages; and as pilot fuel. Pilot fuel is used to ignite the gaseous portion of 

the fuel charge and shall be used according to the manufacture's specifications. Natural gas curtailment is 

defined as period when the natural gas provider/supplier imposes a curtailment or interruption of service, 

and the curtailment is involuntary and beyond the control of the permittee. [Authority granted under 

R307-401-8(1)(a) (BACT); condition originated in DAQE-AN0795006-04]. 

II.B.2.b.1 Monitoring: 

An operation log shall be used to record the engine running time during start-up, shut-down and 

normal operation. Documentation, such as test reports or manufacturers' specifications, shall be 

available to demonstrate that diesel usage meets the definition of pilot fuel. 

II.B.2.b.2 Recordkeeping: 

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.2.b.3 Reporting: 

A semi-annual monitoring report shall be submitted to the Executive Secretary in accordance 

with Provision I.S.2 of this permit. An annual compliance certification shall be submitted to the 

Executive Secretary in accordance with Provision I.L of this permit. 

II.B.2.c Condition: 

Combined hours of operation shall be no greater than 48 hours per day for the four engines. [Authority 

granted under R307-401-8(1)(a)[BACT]; condition originated in DAQE-AN0795006-04]. 

II.B.2.c.1 Monitoring: 

An hour meter installed on each unit shall be used to continuously monitor the hours of operation 

for the affected equipment. 

II.B.2.c.2 Recordkeeping: 

Operational hours of each engine shall be recorded daily. 

Compliance with the limitation shall be determined daily by taking readings of each meter and 

summing the hours of operation for all engines. 

Results shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.2.c.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

Project OPP0107950007 Page 16 Title V Operating Permit #4900018003 
II.B.2.d Condition: 

Visible emissions shall be no greater than 10 percent opacity except for 15 minutes at start-up and 

shutdown. When straight diesel fuel is used, visible emissions shall be no greater than 20 percent opacity 

except for operation not exceeding 3 minutes in any hour. [Authority granted under R307-401-8(1)(a) 

[BACT] and R307-305-3(3); condition originated in DAQE-AN0795006-04]. 

II.B.2.d.1 Monitoring: 

Opacity observations of emissions shall be conducted semi-annually in accordance with 40 CFR 

60, Appendix A, Method 9. 

II.B.2.d.2 Recordkeeping: 

Results of all monitoring shall be recorded and maintained in accordance with the associated test 

method and Provision S.1 in Section I of this permit. 

II.B.2.d.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.2.e Condition: 

Sulfur content of the fuel oil combusted shall be no greater than 0.45 percent by weight. [Authority 

granted under R307-401-8(1)(a) [BACT]; condition originated in DAQEAN0795006-04]. 

II.B.2.e.1 Monitoring: 

Compliance with this limitation shall be determined either by testing each fuel delivery for the 

sulfur content or by inspection of the fuel sulfur-content specifications provided by the vendor in 

purchase records. Sulfur content in either instance shall be determined in accordance with 

ASTM-4294, or equivalent. 

II.B.2.e.2 Recordkeeping: 

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit. 

II.B.2.e.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.3 Conditions on Natural Gas Fired Boilers.

II.B.3.a Condition: 

Emissions of NOx shall be no greater than 1.46 g/kW-hr and 155 ppmdv for each boiler. [Authority 

granted under Utah SIP IX.H.3.d and R307-401-8(1)(a) [BACT]; condition originated in DAQEAN0795006-04]. 

II.B.3.a.1 Monitoring: 

Stack testing shall be performed as specified here: 

Project OPP0107950007 Page 17 Title V Operating Permit #4900018003 
(a) Testing and Frequency. Boiler No. 4 shall be tested every 8,760 hours of operation and/or at 

least every five years based on date of last stack test. Boiler No. 5 shall have an initial test within 

180 days of it becoming active and then testing shall follow the schedule thereafter. 

(b) Notification. At least 30 days before the test, the source shall notify the Executive Secretary 

of the date, time, and place of testing and provide a copy of the test protocol . The source shall 

attend a pretest conference if determined necessary by the Executive Secretary. 

(c) The emission sample point shall be designed to conform to the requirements of 40 CFR 60, 

Appendix A, Method 1. In addition, Occupational Safety and Health Administration (OSHA) 

approved access shall be provided to the test location. (R307-165-2) 

(d) Methods to be used: 

 (1) To determine stack volumetric flow rate - 40 CFR 60, Appendix A, Method 2. 

 (2) To test for NOx emissions - 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, or 

 7E. 

(e) Calculations. To determine mass emission rates (g/kW-hr) the pollutant concentration as 

determined by the appropriate methods above shall be multiplied by the volumetric flow rate, 

divided by the engine's power output during the test and multiplied by any necessary conversion 

factors. 

(f) Production Rate During Testing. The production rate during all compliance testing shall be no 

less than 90% of the maximum production achieved in the previous three (3) years. (R307-165-

3). 

II.B.3.a.2 Recordkeeping: 

Results of all monitoring shall be recorded and maintained in accordance with the associated test 

method and Provision S.1 in Section I of this permit. 

II.B.3.a.3 Reporting: 

Results of required stack testing shall be submitted to the Executive Secretary within 30 days of 

completion of the testing. The submittal shall clearly identify results and indicate compliance 

status. The annual compliance certification required by Provision L in Section I of this permit 

shall use the most recent test results as a basis for stating compliance status for this limitation. 

II.B.3.b Condition: 

Visible emissions shall be no greater than 0 percent opacity except for 15 minutes at start-up when the 

boilers are cold. [Authority granted under R307-401-8(1)(a) [BACT]; condition originated in DAQEAN0795006-04]. 

II.B.3.b.1 Monitoring: 

Opacity observations of emissions shall be conducted semi-annually in accordance with 40 CFR 

60, Appendix A, Method 9. 

Project OPP0107950007 Page 18 Title V Operating Permit #4900018003 
II.B.3.b.2 Recordkeeping: 

Results of all monitoring shall be recorded and maintained in accordance with the associated test 

method and Provision S.1 in Section I of this permit. 

II.B.3.b.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.4 Conditions on Emergency Generator.

II.B.4.a Condition: 

Visible emissions shall be no greater than 20 percent opacity except for 15 minutes at start-up and 

shutdown.. [Authority granted under R307-401-8(1)(a) [BACT] and R307-305-3(3); condition originated 

in DAQE-AN0795006-04]. 

II.B.4.a.1 Monitoring: 

Opacity observations of emissions shall be conducted every 50 hours of operation in accordance 

with 40 CFR 60, Appendix A, Method 9. 

II.B.4.a.2 Recordkeeping: 

Results of all monitoring shall be recorded and maintained in accordance with the associated test 

method and Provision S.1 in Section I of this permit. 

II.B.4.a.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.4.b Condition: 

Emergency generators shall be used for electricity producing operation only during the periods when 

electric power from the public utilities is interrupted, or for regular maintenance of the generators. 

[Authority granted under R307- 401- 8(1)(a) (BACT); condition originated in DAQE-AN0795006-04]. 

II.B.4.b.1 Monitoring: 

Records required for this permit condition will serve as monitoring. 

II.B.4.b.2 Recordkeeping: 

Records documenting generator usage shall be kept in a log and they shall show the date the 

generator was used, the duration in hours of the generator usage, and the reason for each 

generator usage. 

Project OPP0107950007 Page 19 Title V Operating Permit #4900018003 
II.B.4.b.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.B.4.c Condition: 

The permittee shall combust only #1 or #2 low sulfur fuel oils. [Authority granted under R307-401-

8(1)(a) [BACT]; condition originated in DAQE-AN0795006-04]. 

II.B.4.c.1 Monitoring: 

Records required for this permit condition will serve as monitoring. 

II.B.4.c.2 Recordkeeping: 

Fuel receipts shall be maintained to demonstrate usage of the following lowsulfur fuels having a 

sulfur content less than 0.5 percent by weight: Grade Low Sulfur No. 1 Diesel, Grade Low Sulfur 

No. 2 Diesel, Grade No. 1 Diesel, Grade No. 2 Diesel. 

II.B.4.c.3 Reporting: 

There are no reporting requirements for this provision except those specified in Section I of this 

permit. 

II.C Emissions Trading 

(R307-415-6a(10)) 

 Not applicable to this source.

II.D Alternative Operating Scenarios. 

 (R307-415-6a(9)) 

 Not applicable to this source.

 

II.E Source-specific Definitions- There are no source specific definitions. 

SECTION III: PERMIT SHIELD

A permit shield was not granted for any specific requirements. 

SECTION IV: ACID RAIN PROVISIONS

IV.A This source is not subject to Title IV. This section is not applicable. 

Project OPP0107950007 Page 20 Title V Operating Permit #4900018003 
REVIEWER COMMENTS

This operating permit incorporates all applicable requirements contained in the following documents: 

Incorporates Utah SIP IX.H.3.d dated July 6, 2005 

Incorporates DAQE-AN0795006-04 dated December 10, 2004 

 1. Comment on an item originating in regarding Permitted Source 

regarding Permitted Source: Compliance Assurance Monitoring (CAM )applicability has 

been evaluated. There are no CAM requirements in this permit. [Last updated June 9, 

2009] 

 2. Comment on an item originating in regarding Dual Fuel Internal Combustion Engines 

DAQE-032-97, Condition #11 regarding Dual Fuel Internal Combustion Engines (Unit 

Engines) [This is a historical comment]: Fuel Usage: The "dual fuel" engine is defined as a 

gaseous fueled engine using the 

combustion of a tiny spray of liquid diesel fuel to ignite the gas-air mixture in place of 

a spark plug. The tiny bit of liquid diesel fuel is called "pilot fuel" because it acts as a 

"pilot light" to ignite the gaseous portion of the fuel charge. 

The traditional "dual fuel" engine uses about 95% gaseous fuel ignited by about 5% 

liquid pilot fuel at a full load normal operation, in terms of heat input. The amount of 

diesel fuel injected to an engine is fixed by rack setting while the natural gas is supplied 

based on the loading requirement. The proportion of fuel consumption during normal 

operation is a feature of an engine design, therefore, documentation showing the 

engine's pilot fuel usage recommended from the manufacturer shall be able to 

demonstrate compliance with the pilot fuel condition. It does not make sense for the 

owner/operator to use more diesel fuel since the purpose of the pilot fuel is to ignite the 

combustion and diesel is much more expensive than the natural gas. [Last updated July 8, 

2009] 

 3. Comment on an item originating in regarding Dual Fuel Internal Combustion Engines 

DAQE-032-97, Condition #8 regarding Dual Fuel 

Internal Combustion Engines (Unit Engines): Visible Emissions: There are several periods 

when the visible emissions from engines 

can exceed 10% opacity, i.e., during shut-down, maintenance firing, break in firing and 

natural gas curtailment when straight fuel oil is used. The operating permit application 

requests the exemption from 10% opacity limit for these periods. R307-305-1 requires 

that visible emissions from diesel engines manufactured after January 1, 1973 be no 

greater than 20% opacity, the engines used in the plant were manufactured after 1973, 

therefore, 20% opacity is required when straight diesel is used. 

Note: The above is a historical comment on conditions of approval order DAQE-032-97. 

The document has since been replaced by DAQE-AN0795006-04 which explicitly 

requires: 

¿¿10 percent opacity except for 15 minutes at start-up and shutdown. When straight diesel 

fuel is used, visible emissions shall be no greater than 20 percent opacity except for 

operation not exceeding 3 minutes in any hour.¿ 

 [Last updated June 16, 2009] 

Project OPP0107950007 Page 21 Title V Operating Permit #4900018003 
 4. Comment on an item originating in regarding Dual Fuel Internal Combustion Engines 

regarding Dual Fuel Internal Combustion Engines (Unit Engines), requirements of the 

Utah SIP IX.H.1.b.D and DAQE-032-97 : Emission testing requirement (historical 

comment): : The current Approval Order requires stack testing frequence of every three 

years. This requirement is changed based on the varied 

operational schedule of the plant. The internal combustion (I/C) engines and boilers in 

the power plant are back up generation units. In good water years, hydroelectric 

generation is abundant and IC engines and boilers are ready reserve generation. In the 

years of 1994 and 1995, each engine operated less than 30 hours. In the year of 1995, 

only one boiler operated for 177 hours. During a three years period, each engine and 

Revised February 22, 2005 Page 17 Title V Operating Permit #4900018002 

boiler may operate less than 100 hours and 600 hours, respectively. In a 12 month 

period ending June 30, 2001 Engine 1 operated 535 hours, 2 - 464 hours, 3 - 471 hours, 

4 - 399 hours. It is not justifiable to require a stack test every three years. However, 

the IC engines and boilers would operate more hours in a bad water year. Therefore, it 

is more reasonable to require emission testing after certain hours of operation. 

The recent stack tests conducted in 2000 indicated that the highest NOx concentration 

and emission rate were 418 ppmdv and 5.94 g/kW-hr, respectively for the four engines 

tested (Limitions are 1,660 ppmdv and 10.4 g/kW-hr). For boiler No.4, NOx

concentration are emission rate were 99 ppmdv and 0.94 g/kW-hr, respectively 

(limitions are 155 ppmdv and 1.46 g/kW-hr). The test results showed a safe margin of 

compliance. Boiler No. 5 is not currently operational and there is no recent stack test 

data. Special initial testing requirement will be set for this boiler. 

Note: The above is a historical comment on conditions of the Utah SIP IX.H.1.b.D, and the 

approval order DAQE-032-97. Those two documents have since been replaced by Utah 

SIP IX.H.3.d, and DAQE-AN0795006-04 which require testing every 8,760 hours of 

operation, and at least every five years. [Last updated July 2, 2009] 

Project OPP0107950007 Page 22 Title V Operating Permit #4900018003