## 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 Polluti on 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 th e 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 informatio n in January 2009. The new emissions control equipment will consist of low-NO

x burners, replacement of the ESP with a fabric filter, and upgrade of the flue gas desulfurization system. In addition, P acifiCorp Energy is requesting plantwide applicability

limits for SO 2 and NO

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

The installation of the low-NO

x 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 Pe rmit 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: PM 10 = -835, NO

x = -546, SO 2 = -13,921, CO = +7,109, VOC = +25, and H 2 SO 4 = -14.8. The change in emissions will result in the fo llowing, in tons per year, totals for the plant: PM 10 = 925, NO

x = 11,356, SO 2 = 5,220, CO = 14,218, VOC = 119, and H 2 SO 4 = 1.6. Established PALs for the plant include the PSD significance level of 40 tons per year, and are set at NO

x = 11,396 tons/year and

SO 2 = 5,260 tons/year based on a 12-month rolling average.

This air quality AO authorizes the project with the foll owing 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 refere nces used in this AO conform to those used in

the UAC R307 and 40 CFR. Unless noted otherw ise, 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 pro cesses 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 a nd operate any equipment approved under this AO, including associated air pollution control equipm ent, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being u sed 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 aut horized by this AO shall be recorded. [R307-401-4]

I.6 The owner/operator shall comply with R307-1 50 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 NO

x burners with overfire air system, and an SO 2 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-NO

x burners with overfire air system, and an SO 2 FGD scrubber.

II.A.4 Coal Storage Existing covered coal storage facility and ope n 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 (die sel 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 emergenc y diesel generators and fire pumps. No unit-specific applicable requirements.

II.A.18 Lube Oil Storage Tanks Four 10,000 gallon tanks that store lubricati ng 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 Deg reasing Operations Bench-top cold degreasing units using Safety-K leen, 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 associat ed dispensing equipment to refuel fleet vehicles and mobile equipment. No uni t-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 c onsisting 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, hydrochl oric 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 hoppe r and associated covered conveyor belts with enclosed transfer stations equipped with dust cl osure 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 w aste 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 (Paci fiCorp) shall notify the Executiv e Secretary in writing when the

installation of each new low-NO

x system, scrubber upgrade and fabric filter baghouse installation listed in II.A has been complete d and is operational, as an initial compliance inspection is required for each system. To in sure proper credit when notifying the Executive Secretary, send your correspondence to the Execu tive Secretary, attn: Compliance Section.

Installation of each new low-NO

x system, scrubber upgrade, and fabric filter baghouse is deemed complete and operational following th e completion of acceptance testing. All pollution control equipment acceptance tests will be completed within 180 days of initial startup of each low-NO

x system, scrubber upgrade, and fa bric 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 emissi ons shall be no greater than 20%. Opacity observations of emissions from stationary so urces shall be conducted in accordance with 40DAQE-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 hand ling 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 visi ble 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 ap plicable 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 Lim its (PALs) for the entire Huntington Plant from all point sources and fugitive emissions shall not exceed the following:

SO 2 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.

NO

x Limit: 11,396 tons/year based on a 12-m onth rolling total begi nning in the month following the installation of the Unit 1 low-NO

x systems. [R307-401]

II.B.1.g.1 The SO 2 and NO

x PALs shall be monitored in accordan ce 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 NO

x and SO 2 in pounds per hour obtained from the boilers' CEM data shall be used to

calculate NO

x and SO 2 emission rates. All reported SO 2 emissions, including emissions associated with startups, shutdowns, and malfunc tions, 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 SO 2 and NO

x 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 a nd the duration in hours of generator usage.

For emergency diesel-fired fire pumps, emissions shall be calculated by multiplying the SO 2 and NO

x 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 accord ance 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 acco rdance 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 NO

x and SO 2 PALs, the owner/operator shall calculate a new 12-month total NO

x and SO 2 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 SO 2 from Boiler Unit #1 shall be no greater than 1.2 lb SO 2 /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 SO 2 from Boiler Unit #1 shall be no greater than 0.12 lb SO 2 /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, calib rate, maintain, and operate a continuous monitoring system for measuring SO 2 emissions. PacifiCorp shall determin e 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, mainta in, and operate a continuous monitoring system, and record the output of the system, for measuring SO 2 emissions. PacifiCorp shall determine compliance with the SO 2 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 PM 10 from Boiler Unit #1 shall not be greater than 74 lb/hr following installation of the fabric filter baghouse except during period s of startup, shutdown, maintenance/planned outage or malfunction. [R307-401]

II.B.2.d Prior to completion of the scrubber upgrade installation emissions of NO

x from Boiler Unit #1 shall be no greater than 0.70 lb/MMBtu heat i nput 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-NO

x system, emissions of NO

x from Boiler Unit #1 shall be no greater than 0.26 lb NO

x /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, calib rate, maintain, and operate a continuous monitoring system for measuring NO

x emissions. PacifiCorp shall determin e 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-NO

x 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/planne d outage, or malfunction.

PacifiCorp shall install, calib rate, 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) sy stem 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 andDAQE-AN0102380021-10 Page 10

except during periods of start up, shutdown, ma intenance/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) a nd (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, ma intenance/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 a nd stack test methods shall be performed according to 40 CFR 60 Subpart D, 60.46. [R307-150]

II.B.3.c Emissions of SO 2 from Boiler Unit #2 shall be no greater than 0.12 lb SO 2 /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 NO

x 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 ma intained including the date and time of each inspection and the name of the person making th e 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. Th is AO in no way releases the owner or operator from any liability for compliance with all other applicable fe deral, 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, 2006DAQE-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

NO

x Oxides of nitrogen

NSPS New Source Performance Standard

NSR New Source Review

PM 10 Particulate matter less than 10 microns in size

PM 2.5 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

SO 2 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 (t ypically interchangeable with DAQ)

VOC Volatile organic compounds