State of Utah 

GARY R. HERBERT 

Governor 

GREG BELL 

Lieutenant Governor

Department of 

Environmental Quality 

Amanda Smith 

Executive Director 

DIVISION OF AIR QUALITY 

Cheryl Heying 

Director 

 

DAQE-AN0102380021-10 

January 19, 2010 

Jim Doak 

PacifiCorp Energy 

1407 W. North Temple 

Suite 330 

Salt Lake City, UT 84116 

Dear Mr. Doak: 

Re: Approval Order: Installation of Pollution Control Equipment and Establishing Plantwide 

Applicability Limitations 

 Emery County; CDS A; NSPS (Part 60), PSD, Title IV (Part 72 / Acid Rain), Title V (Part 70), 

Title V (Part 70) Major source 

 Project Number: N0102380021 

The attached document is the Approval Order for the above-referenced project. Future correspondence 

on this Approval Order should include the engineer's name as well as the DAQE number as shown on the 

upper right-hand corner of this letter. The project engineer for this action is John Jenks, who may be 

reached at (801) 536-4459. 

Sincerely, 

M. Cheryl Heying, Executive Secretary 

Utah Air Quality Board 

MCH:JJ:dn 

cc: Mike Owens 

 Southeastern Utah District Health Department 

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 
STATE OF UTAH 

Department of Environmental Quality 

Division of Air Quality 

APPROVAL ORDER: Installation of Pollution Control Equipment 

and Establishing Plantwide Applicability Limitations 

Prepared By: John Jenks, Engineer 

Phone: (801) 536-4459 

Email: jjenks@utah.gov 

APPROVAL ORDER NUMBER 

DAQE-AN0102380021-10 

Date: January 19, 2010 

PacifiCorp Energy 

Huntington Power Plant 

Source Contact: 

Mr. Darrell Cunningham 

Phone: (435) 687-4211 

M. Cheryl Heying 

Executive Secretary 

Utah Air Quality Board 
Abstract

This is an Administrative Amendment to correct a date reference in DAQE-AN0102380020-09. The 

original abstract is included below. 

On April 15, 2008, PacifiCorp Energy submitted an NOI to install new emissions control equipment at 

the Huntington Power Plant on the Unit #1 boiler in order to substantially reduce plant emissions. The 

NOI was supplemented with CO modeling information in January 2009. The new emissions control 

equipment will consist of low-NOx burners, replacement of the ESP with a fabric filter, and upgrade of 

the flue gas desulfurization system. In addition, PacifiCorp Energy is requesting plantwide applicability 

limits for SO2 and NOx emissions, along with lower emission limits at Unit #1 for those same pollutants. 

The installation of the low-NOx burners on Unit #1 may increase CO emissions. In addition, past PTE 

emissions of CO were estimated using now-outdated emission factors. These two issues result in a new 

PTE for CO above the PSD significance threshold of 100 tons per year. Therefore a PSD modification 

for CO is required. 

The Unit #1 and #2 boilers are subject to NSPS Subpart D. Title IV and Title V of the 1990 Clean Air 

Act apply to this source. The Title V Operating Permit will be updated prior to operating the modified 

equipment. The source is located in Emery County, which is an attainment area for all pollutants. After 

the installation and upgrades of the control equipment, the emissions from the #1 boiler, in tons per year, 

will change as follows: PM10 = -835, NOx = -546, SO2 = -13,921, CO = +7,109, VOC = +25, and H2SO4

= -14.8. The change in emissions will result in the following, in tons per year, totals for the plant: PM10

= 925, NOx = 11,356, SO2 = 5,220, CO = 14,218, VOC = 119, and H2SO4 = 1.6. Established PALs for 

the plant include the PSD significance level of 40 tons per year, and are set at NOx = 11,396 tons/year and 

SO2 = 5,260 tons/year based on a 12-month rolling average.

This air quality AO authorizes the project with the following conditions and failure to comply with any of 

the conditions may constitute a violation of this order. This AO is issued to, and applies to the following: 

Name of Permittee:

PacifiCorp Energy 

1407 W. North Temple 

Suite 330 

Salt Lake City, UT 84116 

Permitted Location:

PacifiCorp: Huntington Power Plant 

P. O. Box 680 

Huntington, UT 84528 

 

UTM coordinates: 493130 m Easting, 4358840 m Northing 

SIC code: 4911 (Electric Services) 

Section I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in 

the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions 

refer to those rules. [R307-101] 

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] 

I.3 Modifications to the equipment or processes approved by this AO that could affect the 

emissions covered by this AO must be reviewed and approved. [R307-401-1] 
DAQE-AN0102380021-10 

Page 3

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by 

the owner/operator, shall be made available to the Executive Secretary or Executive Secretary's 

representative upon request, and the records shall include the two-year period prior to the date of 

the request. Unless otherwise specified in this AO or in other applicable state and federal rules, 

records shall be kept for a minimum of five (5) years. [R307-415-6b] 

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators 

shall, to the extent practicable, maintain and operate any equipment approved under this AO, 

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. 

All maintenance performed on equipment authorized by this AO shall be recorded. 

[R307-401-4] 

I.6 The owner/operator shall comply with R307-150 Series. Inventories, Testing and Monitoring. 

[R307-150] 

I.7 The owner/operator shall comply with UAC R307-107. General Requirements: Unavoidable 

Breakdowns. [R307-107] 

Section II: SPECIAL PROVISIONS

II.A The approved installations shall consist of the following equipment: 

II.A.1 Huntington Power Plant 

Two nominal 480 MW utility boilers 

II.A.2 Boiler Unit #1 

Nominal 480 MW gross capacity dry bottom, tangentially-fired utility boiler fired on 

subbituminous and bituminous coal using fuel oil during startup & flame stabilization. 

Equipped with a fabric filter baghouse, low NOx burners with overfire air system, and an SO2

FGD scrubber. NSPS Subpart D. 

II.A.3 Boiler Unit #2 

Nominal 480 MW gross capacity dry bottom tangentially-fired utility boiler fired on 

subbituminous and bituminous coal using fuel oil during startup & flame stabilization. 

Equipped with a fabric filter baghouse, low-NOx burners with overfire air system, and an SO2

FGD scrubber. 

II.A.4 Coal Storage 

Existing covered coal storage facility and open coal pile. No unit-specific applicable 

requirements. 

II.A.5 Ash Landfill 

Ash and sludge disposal. No unit-specific applicable requirements. 
DAQE-AN0102380021-10 

Page 4

II.A.6 Unit #1 Cooling Towers 

Unit #1 cooling towers for the circulating water system. 

II.A.7 Unit #2 Cooling Towers 

Unit #2 cooling towers for the circulating water system. 

II.A.8 Coal Conveyors 

Coal transfer on plant site. 

II.A.9 Ash Haul Road (dirt) 

Unpaved ash haul road. 

II.A.10 Ash Haul Road (paved) 

Paved ash haul road. 

II.A.11 Unit #1 Emergency Generator (diesel engine) 

Emergency generator (diesel engine) for Unit #1 

. 

II.A.12 Unit #2 Emergency Generator (diesel engine) 

Emergency generator (diesel engine) for Unit #2. 

II.A.13 Emergency Fire Pump (diesel engine) 

Emergency fire pump (diesel engine). 

II.A.14 Coal Silo System Exhauster for Unit #1 

Coal silos for Unit #1 equipped with exhausters and dust collectors. 

II.A.15 Coal Silo System Exhauster for Unit #2 

Coal silos for Unit #2 equipped with exhausters and dust collectors. 

II.A.16 Lime silo 

Lime silo bin vent 

II.A.17 Distillate Fuel Oil Tanks 

Three 70,000 gallon tanks (1973) and day tanks for the emergency diesel generators and fire 

pumps. No unit-specific applicable requirements. 

II.A.18 Lube Oil Storage Tanks 

Four 10,000 gallon tanks that store lubricating oil including vents and associated equipment; 

two each constructed in 1973 and 1975. No unit-specific applicable requirements. 

II.A.19 Oil Storage Area 

Storage area for oil contained in closed 55 gallon drums. No unit-specific applicable 

requirements. 

II.A.20 Paved Access Road and Parking Area 

Paved access road from the plant entrance to the administration building and parking area. No 

unit-specific applicable requirements. 
DAQE-AN0102380021-10 

Page 5

II.A.21 Cold Solvent Degreasing Operations 

Bench-top cold degreasing units using Safety-Kleen, Simple Green, or other comparable 

degreasing agents. No unit-specific applicable requirements 

. 

II.A.22 Miscellaneous Electrical Equipment 

Fugitive emission units including transformer insulating oil. No unit-specific applicable 

requirements. 

II.A.23 Diesel Refueling Stations and Storage Tanks 

Miscellaneous fuel storage tanks and associated dispensing equipment to refuel fleet vehicles 

and mobile equipment. No unit-specific applicable requirements. 

II.A.24 Gasoline Vehicle Refueling Station and Tanks 

Miscellaneous gasoline storage tanks and associated dispensing equipment to refuel fleet 

vehicles and mobile equipment. No unit-specific applicable requirements. 

II.A.25 Unit #1 Generator Seal Oil Air Detraining Tanks 

Atmospheric vents from the seal oil air detraining tanks for Boiler Unit #1. 

II.A.26 Unit #2 Generator Seal Oil Air Detraining Tanks 

Atmospheric vents from the seal oil air detraining tanks for Boiler Unit #2. 

II.A.27 Unit #1 Lube Oil Reservoirs 

Lube oil reservoirs with vapor extractors for Boiler Unit #1. 

II.A.28 Unit #2 Lube Oil Reservoirs 

Lube oil reservoirs with vapor extractors for Boiler Unit #2. 

II.A.29 Truck Mounted Vacuum System 

Mobile truck mounted vacuum to clean up spilled material such as ash. 

II.A.30 Ash Unloader for Unit #1 

Equipment for unloading ash from silos and into trucks for transport to the ash landfill. 

II.A.31 Ash Unloader for Unit #2 

Equipment for unloading ash from silos and into trucks for transport to the ash landfill. 

II.A.32 Emission Units Subject to 40% Opacity Limit 

Units constructed prior to April 25, 1971 consisting of Boiler Unit #2 coal silo system 

exhauster, Unit #2 ash unloader, Unit #2 Generator Seal Oil Air Detraining Tanks, Unit #2 

Lube Oil Reservoir, and the coal reject handling system (Emission Unit #35). 

II.A.33 Coal Reject Handling System 

Material handling system that separates reject materials from the coal prior to pulverizing. 

II.A.34 Hazardous Waste Storage Area 

Area where hazardous waste is stored temporarily awaiting disposal. 

II.A.35 Electro-hydraulic Control Reservoirs 

Three 400 gallon tanks that store lubricating oil. 
DAQE-AN0102380021-10 

Page 6

II.A.36 Water Treatment Chemical Tanks 

Tank storage including sulfuric acid, hydrochloric acid, lime, soda ash, sodium hydroxide, 

anti-scale, and other miscellaneous water treatment chemicals. 

II.A.37 Paint Storage Areas 

Various storage areas for sealed paint containers. 

II.A.38 Coal handling and Blending Equipments 

Includes truck unloading hopper enclosed on the sides with water sprays, covered conveyor 

belts with enclosed transfer stations, radial stacker, Stamler feeder with water sprays, and 

screens. NSPS Subpart Y. 

II.A.39 Real Time Coal Analyzer 

Thermo Electron CQM coal analyzer with hopper and associated covered conveyor belts with 

enclosed transfer stations equipped with dust closure seals and curtains at all loading points. 

II.A.40 Unit #2 fabric filter for fly ash bin vent 

One fabric filter for fly ash silo bin vent 

II.A.41 Unit #2 Fabric filters group 

Includes two fabric filters for each of the two waste lime day bin vents, one fabric filter for 

lime silo vent, and two fabric filters for each of the two lime silo day bin vents. 

II.A.42 Research farm water pump 

27.5 HP diesel-driven water pump 

II.B Requirements and Limitations 

II.B.1 Conditions on Permitted Source

II.B.1.a PacifiCorp Energy (PacifiCorp) shall notify the Executive Secretary in writing when the 

installation of each new low-NOx system, scrubber upgrade and fabric filter baghouse 

installation listed in II.A has been completed and is operational, as an initial compliance 

inspection is required for each system. To insure proper credit when notifying the Executive 

Secretary, send your correspondence to the Executive Secretary, attn: Compliance Section. 

Installation of each new low-NOx system, scrubber upgrade, and fabric filter baghouse is 

deemed complete and operational following the completion of acceptance testing. All 

pollution control equipment acceptance tests will be completed within 180 days of initial 

startup of each low-NOx system, scrubber upgrade, and fabric filter baghouse installation. 

If installation has not been completed within 18 months from the date of DAQEAN0102380019-09 (August 6, 2009), the Executive Secretary shall be notified in writing on 

the status of the installation. At that time, the Executive Secretary shall require documentation 

of the continuous installation of the operation and may revoke the AO in accordance with 

R307-401-18. [R307-401-18] 

II.B.1.b All coal conveyors and drop points shall be enclosed. [R307-401] 

II.B.1.c Except as outlined below, visible emissions shall be no greater than 20%. Opacity 

observations of emissions from stationary sources shall be conducted in accordance with 40 
DAQE-AN0102380021-10 

Page 7

CFR 60, Appendix A, Method 9. For sources that are subject to NSPS, opacity shall be 

determined by conducting observations in accordance with 40 CFR 60.11(b) and 40 CFR 60, 

Appendix A, Method 9. [R307-401] 

II.B.1.c.1 Visible emissions from the coal reject handling system shall be no greater than 40% opacity. 

[R307-401] 

II.B.1.c.2 Visible emissions shall be no greater than 5% opacity at all conveyor transfer points and 

conveyor drop points for the coal blending equipment. [R307-401] 

II.B.1.c.3 Visible emissions shall be no greater than 10% opacity for the truck unloading hopper, radial 

stacker, and all screens. [R307-401] 

II.B.1.c.4 There shall be no visible emissions at the Real-Time coal analyzer and all associated conveyor 

transfer points and conveyor drop points. 

A visual observation of the site shall be made at least once each month. A log of the visual 

observations shall be maintained, including the date and time of each inspection and the name 

of the person making the inspection. Any visible emissions observed shall be reported as a 

deviation. [R307-401] 

II.B.1.d The owner/operator shall abide by the latest fugitive dust control plan approved by the 

Executive Secretary for control of all dust sources associated with the Huntington Power Plant. 

The dust control plan shall meet all applicable requirements of R307-205 for Fugitive 

Emissions and Fugitive Dust Sources. [R307-205] 

II.B.1.e The owner/operator shall abide by all applicable requirements of R307-206 for Abrasive 

Blasting Emission Standards. [R307-206] 

II.B.1.f The sulfur content of any fuel oil shall not exceed 0.85 lbs/MMBtu heat input. The sulfur 

content shall be determined by ASTM methods D2015-88 or D3286-85 or approved 

equivalent. [R307-401] 

II.B.1.g At all times the Plantwide Applicability Limits (PALs) for the entire Huntington Plant from all 

point sources and fugitive emissions shall not exceed the following: 

SO2 Limit: 5,260 tons/year based on a 12-month rolling total beginning in the month 

following the installation of the Unit 1 FGD upgrades. 

NOx Limit: 11,396 tons/year based on a 12-month rolling total beginning in the month 

following the installation of the Unit 1 low-NOx systems. 

[R307-401] 

II.B.1.g.1 The SO2 and NOx PALs shall be monitored in accordance with 40 CFR Part 52.21.21(aa)(12) 

and at a minimum it shall be done by summing up emissions from the: 

Units #1 and #2 main boiler stacks, PacifiCorp's reporting to EPA's Acid Rain Emissions data 

base for NOx and SO2 in pounds per hour obtained from the boilers' CEM data shall be used to 

calculate NOx and SO2 emission rates. All reported SO2 emissions, including emissions 

associated with startups, shutdowns, and malfunctions, in pounds per hour, shall be summed to 

get monthly total emissions. 
DAQE-AN0102380021-10 

Page 8

For emergency diesel-fired generators, emissions shall be calculated by multiplying the SO2

and NOx emission factor from latest edition of the EPA's emission factors compilation AP-42 

and hours of operation. Records documenting generator usage shall be kept in a log and they 

shall show the date the generator was used and the duration in hours of generator usage. 

For emergency diesel-fired fire pumps, emissions shall be calculated by multiplying the SO2

and NOx emission factor from latest edition of the EPA's emission factors compilation AP-42 

and hours of operation. Records documenting generator usage shall be kept in a log and they 

shall show the date the pump was used, and the duration in hours of pump usage. 

The PAL above shall be effective for ten years from the date of issuance of DAQEAN0102380019-09 (August 6, 2009), in accordance with 40 CFR Subpart 52.21(aa). 

If PacifiCorp applies for PAL renewal, the application in accordance with 40 CFR Subpart 

52.21(aa)(10) shall be submitted before the end of the PAL effective date and the PAL 

established in this approval order will remain until a revised approval order is issued. 

Once the PAL expires, the source is subject to the requirements of 40 CFR Subpart 

52.21(aa)(9). 

Monitoring for each PAL shall be in accordance with 40 CFR Subpart 52.21(aa)(12). 

For the record keeping requirements of each PAL, PacifiCorp shall comply with 40 CFR 

Subpart 52.21(aa)(13). 

For record submittal, PacifiCorp shall comply with 40 CFR Subpart 52.21(aa)(14). [R307-

401] 

II.B.1.g.2 To determine compliance with the applicable 12-month rolling NOx and SO2 PALs, the 

owner/operator shall calculate a new 12-month total NOx and SO2 emissions by the twentieth 

day of each month using data from the previous 12 months. Records of emissions shall be 

kept for all periods when the plant is in operation. [R307-150] 

II.B.2 Conditions on Boiler Unit #1

II.B.2.a Prior to completion of the scrubber upgrade installation, emissions of SO2 from Boiler Unit #1 

shall be no greater than 1.2 lb SO2/MMBtu heat input for any 3-hour period. This shall be 

determined by the arithmetic average of three contiguous 1-hour periods except during periods 

of startup, shutdown, maintenance/planned outage, or malfunction. 

Following completion of the scrubber upgrade installation, emissions of SO2 from Boiler Unit 

#1 shall be no greater than 0.12 lb SO2/MMBtu heat input (595 lb/hr) on a 30-day rolling 

average except during periods of startup, shutdown, maintenance/planned outage or 

malfunction. 

PacifiCorp shall install, calibrate, maintain, and operate a continuous monitoring system for 

measuring SO2 emissions. PacifiCorp shall determine compliance by periodic monitoring 

using procedures in 40 CFR Part 60.45, Emission and fuel monitoring (subparagraphs (a), (e), 

and (f)) and 60.13(e). [R307-401] 
DAQE-AN0102380021-10 

Page 9

II.B.2.b PacifiCorp shall install, calibrate, maintain, and operate a continuous monitoring system, and 

record the output of the system, for measuring SO2 emissions. PacifiCorp shall determine 

compliance with the SO2 reduction limit by periodic monitoring using procedures in 40 CFR 

Part 60.46a, Compliance provision (subparagraph (c), (d), (e), (g) and (h)), 60.47a, Emission 

monitoring (subparagraph (b), (d), (e), (f), (g), (h), (i) and (j)), and 60.48a, Compliance 

determination procedures and methods (subparagraph (c)). [40 CFR 60] 

II.B.2.c Prior to completion of the scrubber upgrade installation emissions of particulate matter (PM) 

from Boiler Unit #1 shall not be greater than 0.10 lb/MMBtu heat input except during periods 

of startup, shutdown, maintenance/planned outage or malfunction. 

Emissions of PM10 from Boiler Unit #1 shall not be greater than 74 lb/hr following installation 

of the fabric filter baghouse except during periods of startup, shutdown, maintenance/planned 

outage or malfunction. [R307-401] 

II.B.2.d Prior to completion of the scrubber upgrade installation emissions of NOx from Boiler Unit #1 

shall be no greater than 0.70 lb/MMBtu heat input for any 3-hour period. This shall be 

determined by the arithmetic average of three contiguous 1-hour periods except during periods 

of startup, shutdown, maintenance/planned outage or malfunction. 

Following installation of the Unit #1 low-NOx system, emissions of NOx from Boiler Unit #1 

shall be no greater than 0.26 lb NOx/MMBtu heat input (1,290 lb/hr) on a 30-day rolling 

average except during periods of startup, shutdown, maintenance/planned outage, or 

malfunction. 

PacifiCorp shall install, calibrate, maintain, and operate a continuous monitoring system for 

measuring NOx emissions. PacifiCorp shall determine compliance by periodic monitoring 

using procedures in 40 CFR Part 60.45, Emission and fuel monitoring (subparagraphs (a), (e), 

and (f)) and 60.13(e). [R307-401] 

II.B.2.e Following installation of the Unit #1 low-NOx system emissions of CO shall be no greater than 

0.34 lb CO/MMBtu (1,686 lb/hr) on a 30-day rolling average except during periods of startup, 

shutdown, maintenance/planned outage, or malfunction. 

PacifiCorp shall install, calibrate, maintain, and operate a continuous monitoring system for 

measuring CO emissions. The monitoring system shall comply with all applicable sections of 

R307-170; 40 CFR 60.13; and 40 CFR 60, Appendix B. [R307-401] 

II.B.2.f Visible emissions shall be no greater than 20 percent opacity (6-minute average) except for 

one 6-minute period per hour of not more than 27 percent opacity and except during periods of 

start up, shutdown, maintenance/planned outage, or malfunction. 

PacifiCorp shall determine compliance with the visible emission limit by periodic monitoring 

using a continuous opacity monitoring (COM) system installed and operated in accordance 

with 40 CFR 60.45, Emission and fuel monitoring (subparagraphs (a) and (g)) and 60.13(e). 

[R307-401] 

II.B.3 Conditions on Boiler Unit #2

II.B.3.a Visible emissions from Boiler Unit #2 shall be no greater than 20 percent opacity (6-minute 

average) except for one 6-minute period per hour of not more than 27 percent opacity and 
DAQE-AN0102380021-10 

Page 10

except during periods of start up, shutdown, maintenance/planned outage, or malfunction. 

PacifiCorp shall determine compliance with the visible emission limit by periodic monitoring 

using a COM system installed and operated in accordance with 40 CFR 60.45, Emission and 

fuel monitoring (subparagraphs (a) and (g)) and 60.13(e). [40 CFR 60] 

II.B.3.b Emissions of particulate matter (PM) from Boiler Unit #2 shall not be greater than 70 lb/hr, 

except during periods of startup, shutdown, maintenance/planned outage or malfunction. 

[R307-401] 

II.B.3.b.1 Stack testing to show compliance with the PM emission limitations shall be performed as 

specified below: 

(1). Testing and Frequency. Emissions shall be tested each year. The source may also be tested 

at any time if directed by the Executive Secretary. 

(2). Notification. The permittee shall provide a notification of the test date at least 30 days 

before the test. A pretest conference shall be held, if directed by the Executive Secretary, 

between the permittee, the tester, and the Executive Secretary. 

(3). Compliance determination procedures and stack test methods shall be performed 

according to 40 CFR 60 Subpart D, 60.46. [R307-150] 

II.B.3.c Emissions of SO2 from Boiler Unit #2 shall be no greater than 0.12 lb SO2/MMBtu heat input 

for any 24-hour block average except during periods of startup, shutdown, 

maintenance/planned outage, or malfunction. [R307-401] 

II.B.3.d Emissions of NOx from Boiler Unit #2 shall be no greater than 0.26 lb/MMBtu heat input on a 

30-day rolling average except during periods of startup, shutdown, maintenance/planned 

outage or malfunction. [R307-401] 

II.B.3.e Visible emissions from the following Unit #2 emission points shall not exceed 10% opacity: 

(1) Fly Ash Silo Bin Vent (baghouse), 

(2) Waste Lime Day Bin Vent (two baghouses), 

(3) Lime Silo Vent (baghouse), 

(4) Lime Day Bin Vents (two baghouses). 

Opacity observations of emissions from stationary sources shall be conducted according to 40 

CFR 60, Appendix A, Method 22-like procedures. 

A visual observation of the site shall be made at least once a day on item #1 at least once every 

week on items #2, 3 and 4. 

A log of the visual inspections shall be maintained including the date and time of each 

inspection and the name of the person making the inspection. Any observed exceedance of the 

opacity limitation shall be reported as a deviation. [R307-401] 

 Section III: APPLICABLE FEDERAL REQUIREMENTS 

 

In addition to the requirements of this AO, all applicable provisions of the following federal programs 

have been found to apply to this installation. This AO in no way releases the owner or operator from any 

liability for compliance with all other applicable federal, state, and local regulations including UAC 

R307. 
DAQE-AN0102380021-10 

Page 11

NSPS (Part 60), A: General Provisions 

Title IV (Part 72 / Acid Rain), (No subparts) 

NSPS (Part 60), D: Fossil Fuel Boiler After 8/17/71 

NSPS (Part 60), Y: Coal Preparation Plants 

PERMIT HISTORY

This AO is based on the following documents: 

Supersedes DAQE-AN0102380020-10 dated January 4, 2010 

Supersedes DAQE-AN0102380019-09 dated August 6, 2009 

Is Derived From Source submitted NOI addendum dated May 1, 2009 

Is Derived From Source submitted NOI addendum dated January 20, 2009 

Is Derived From Source submitted NOI addendum dated January 6, 2009 

Is Derived From Source submitted NOI dated April 15, 2008 

Supersedes DAQE-AN0238014-06 dated August 18, 2006 
DAQE-AN0102380021-10 

Page 12

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document: 

40 CFR Title 40 of the Code of Federal Regulations 

AO Approval Order 

BACT Best Available Control Technology 

CAA Clean Air Act 

CAAA Clean Air Act Amendments 

CDS Classification Data System (used by EPA to classify sources by size/type) 

CEM Continuous emissions monitor 

CEMS Continuous emissions monitoring system 

CFR Code of Federal Regulations 

CO Carbon monoxide 

COM Continuous opacity monitor 

DAQ Division of Air Quality (typically interchangeable with UDAQ) 

DAQE This is a document tracking code for internal UDAQ use 

EPA Environmental Protection Agency 

HAP or HAPs Hazardous air pollutant(s) 

ITA Intent to Approve 

LB/HR Pounds per hour 

MACT Maximum Achievable Control Technology 

MMBTU Million British Thermal Units 

NAA Nonattainment Area 

NAAQS National Ambient Air Quality Standards 

NESHAP National Emission Standards for Hazardous Air Pollutants 

NOI Notice of Intent 

NOx Oxides of nitrogen 

NSPS New Source Performance Standard 

NSR New Source Review 

PM10 Particulate matter less than 10 microns in size 

PM2.5 Particulate matter less than 2.5 microns in size 

PSD Prevention of Significant Deterioration 

PTE Potential to Emit 

R307 Rules Series 307 

R307-401 Rules Series 307 - Section 401 

SO2 Sulfur dioxide 

Title IV Title IV of the Clean Air Act 

Title V Title V of the Clean Air Act 

TPY Tons per year 

UAC Utah Administrative Code 

UDAQ Utah Division of Air Quality (typically interchangeable with DAQ) 

VOC Volatile organic compounds