PERMITTEE: Sierra Pacific Industries

P.O. Box 496028Redding, CA 96049-6028

FACILITY NAME: Sierra Pacific Industries- Anderson

FACILITY LOCATION: 19758 Riverside Avenue

Anderson, California 96007

Pursuant to the provisions ofthe Clean Air Act (CAA), Subchapter I, Part C (42 U.S.C. Section

7470, et. seq.), and the Code of Federal Regulations (CFR) Title 40, Section 52.21, the United

States Environmental Protection Agency Region 9 (EPA) is issuing a Prevention ofSignjficant

Deterioration (PSD) air quality permit to Sierra Pacific Industries (SPI). This Permit applies tothe approval to construct and operate a new stoker boiler capable of generating 31 MW of gross

electrical output from the combustion of clean cellulosic biomass, and related auxiliary

equipment.

SPI is authorized to construct and operate the 31 MW cogeneration unit at SPI-Anderson as

described herein, in accordance with the permit application (and plans submitted with the permitapplication), the federal PSD regulations at 40 CFR § 52.21, and other terms and conditions set

forth in this PSD Permit. Failure to comply with any condition or term set forth in this PSDPermit may be subject to enforcement action pursuant to Section 113 ofthe Clean Air Act. This

PSD Permit does not relieve SPI from the obligation to comply with applicable federal, state, and

Shasta County Air Quality Management District (District) air pollution control rules and

regulations.

Per 40 CFR § 124.15(b), this PSD Permit becomes effective 30 days after the service of notice of

this final permit decision unless review is requested on the permit pursuant to 40 CFR § 124.19.

- I - /7

Debor Jordan Date

Director, Air Division 

Sierra Pacflc industries (SA C 12-01)

PSD Permit 2013
Sierra Pacific Industries, Inc. (SPI) applied for the approval to construct and operate a new stoker

boiler capable of generating 31 MW of gross electrical output from the combustion of biomass

and natural gas, and related auxiliary equipment. The original Prevention of SignificantDeterioration (PSD) permit for this lumber manufacturing facility was issued in 1994 by the

Shasta County Air Quality Management District(District). The site currently contains a woodfired boiler cogeneration unit with associated air pollution control equipment and conveyance

systems that produce steam to dry lumber in existing kilns. On March 3, 2003, USEPA revoked

and rescinded the District’s authority to issue and modify federal PSD permits for new and

modified major sources of attainment pollutants in Shasta County. Therefore, EPA is issuing this

PSD permit to authorize SPI to construct and operate the additional boiler and related auxiliaryequipment described in this permit at the SPI-Anderson facility. The PSD permit previouslyissued by the District to SPI is still in effect and applies to existing equipment at the SPI

Anderson site.

Fuel for the new stoker boiler will be generated on site and received from other fuel sources,

mainly other SPI facilities, to produce roughly 250,000 pounds per hour ofsteam. This steam

will be used to dry lumber in existing kilns for the lumber operation, as well as feed a turbinethat will drive a generator to produce electricity for use on site or for sale to the grid. A closedloop three-cell cooling tower will be used to dispose of waste heat from the steam turbine.

This PSD permit for the modification requires the use of Best Available Control Technology

(BACT) to limit emissions of nitrogen oxides (NO), carbon monoxide (CO), total particulate

matter (PM), PM under 10 micrometers (jim) in diameter (PM10)and PM under 2.5j.tm in

diameter (PM2.5)to the greatest extent feasible. Air pollution emissions from the modification

will not cause or contribute to violations of any National Ambient Air Quality Standards

(NAAQS) or any applicable PSD increments for the pollutants regulated under the permit.

Additional equipment includes the construction of an additional cooling tower and an emergency

natural gas engine to power the emergency boiler recirculation pump.

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Sierra Pacflc Industries (SAC 12-01)PSD Permit 2013
with (irate • Maximum annual average heat input of approximately 468

MMBIu/hr and steam generation rate of 250,000 lbs/hr

• Equipped with two natural gas burners, each with a maximum

rated heat input of 62.5 MMlitu/hr

• iiuipped with selective non—catalytic reduction (SNCR) system

to reduce NON, and multiclone with an electrostatic precipitator(ESP) to control PM emissions

(32 Cooling Tower • Composed oithree cells with an expected water load o14.24

gallons per minute per square loot.

U3 hrnergency hngine • 256hp at 1,800 rpm

• Spark—ignition internal combustion, natural gas—lired• Powers emergency boiler recirculation pump

• 40 CFR Part 60— Subpart JJJJ Compliant

Table 2 lists the existing equipment that is not included in this PSD permit. The equipment listed

below is permitted by the District and the Permittee must comply with all applicable

requirements. Table 2 is provided for reference purposes only:

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• Equipped with one 30,400 2 hog fuel bins, 2 wood chip

fuel bins

LJ5 One Conveyance System • 2 Cyclones with combined how rate oh’ 51 .004 sclI

• 1 7,11 8 ft2 MAC Pulse Jet Haghouse with 300hp Blower• I 35” x 45” Rotary Airlock• I fluhier en—masse, 19”, 22tph Conveyor

• 2 Each overhead storage bins with enclosed sides

U6 One Spray Unit • Closed ioop unit equipped with integmated. negative pressure,

mist collection system and 65’ exhaust stack

1J7 One Wood Chip Loading • I Platliirrn truck dumper

Facility • 1 Wood chip conveying syStem with dust containment hood

• I 200hp, 5Q000Cl’M Rader blower

118 Seven I)e-greasing Tanks • Non-solvent basedLJ9 One Gas Storage Tank • Above ground with I 0,00() gal Ion capacity

UI 0 One Painting Operation

PERMIT CONDITIONSI. PERMIT EXPIRATION

As provided in 40 CFR § 52.2 1(r), this PSD permit shall become invalid if construction:

A. is not commenced (as defined in 40 CFR § 52.21(b)(9)) within 18 months after the

approval takes effect; or

B. is discontinued for a period of 18 months or more; or

C. is not completed within a reasonable time.

II. PERMIT NOTIFICATION REQUIREMENTS

Permittee shall notify EPA Region IX by letter or by electronic mail ofthe:

A. date construction is commenced, postmarked within 30 days ofsuch date;

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D. date upon which initial performance evaluation ofthe continuous emissions

monitoring system (CEMS) will commence in accordance with 40 CFR § 60.13(c), postmarked not less than 30 days prior to such date. Notification may be provided

with the submittal ofthe CEMS performance test protocol required pursuant to

Condition XL

III. FACILITY OPERATION

A. At all times, including periods ofstartup, shutdown, shakedown, and malfunction,

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

associated air pollution control equipment, in a manner consistent with good air

pollution control practice for minimizing emissions. Determination ofwhether

acceptable operating and maintenance procedures are being used will be based on

information available to EPA, which may include, but is not limited to, monitoring

results, opacity observations, review of operating maintenance procedures and

inspection ofthe Facility.

B. The Permittee shall operate and maintain Ui, U2 and U3 in a manner consistent with

good engineering practices for its full utilization.

C. As soon as practicable following initial startup ofthe facility (as defined in 40 CFR § 60.2) but prior to commencement of commercial operation (as defined in 40 CFR § 72.2), and thereafter, the Permittee shall develop and implement an operation and

maintenance plan for Ui, U2 and U3. At a minimum, the plan shall identify

measures for assessing the performance ofUi, U2, and U3, the acceptable range of

performance measures for achieving the desired output, the methods for monitoring

the performance measures, and the routine procedures for maintaining Ul, U2 and U3

in good operating condition.

IV. MALFUNCTION REPORTING

A. Permittee shall notify EPA at R9.AEOepa.gov within two (2) working days

following the discovery of any failure of air pollution control equipment or process

equipment, or failure of a process to operate in a normal manner, which results in anincrease in emissions above the allowable emission limits stated in Section Xofthis

permit.

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C. Compliance with this malfunction notification provision shall not excuse or otherwise

constitute a defense to any violation ofthis permit or any law or regulation such

malfunction may cause.

V. RIGHT OF ENTRY

The EPA Regional Administrator, and/or an authorized representative, upon the

presentation of credentials, shall be permitted:

A. to enter the premises where the Facility is located or where any records are required

to be kept under the terms and conditions ofthis PSD Permit;

B. during normal business hours, to have access to and to copy any records required to

be kept under the terms and conditions ofthis PSD Permit;

C. to inspect any equipment, operation, or method subject to requirements in this PSD

Permit; and

D. to sample materials and emissions from the source(s).

VI. TRANSFER OF OWNERSHIP

In the event, of any changes in control or ownership ofthe Facility, this PSD Permit shallbe binding on all subsequent owners and operators. Within 14 days of any such changein control or ownership, Permittee shall notifSr the succeeding owner and operator oftheexistence ofthis PSD Permit and its conditions by letter. Permittee shall send a copy of

this letter to EPA Region IX within 30 days of its issuance.

VII. SEVERABILITY

The provisions ofthis PSD Permit are severable, and, if any provision ofthe PSD Permitis held invalid, the remainder ofthis PSD Permit shall not be affected.

VIII. ADHERENCE TO APPLICATION AND COMPLIANCE WITH OTHER

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1X. RESERVED

X. SPECIAL CONDITIONS

A. Boiler Annual Emission Limits

Annual emissions, in tons per year (tpy) on a 12-month rolling average basis, shall not

exceed the following:

Table 3- Ui Rolling 12-Month Emission Limits

II) NO CO PM PM10 PM2,5

UI 267 472 41 41 41

B. Air Pollution Control Equipment and Operation

As soon as practicable following initial startup ofUi (startup as defined in 40 CFR §

60.2) but prior to conm’lencement of commercial operation (as defined in 40 CFR § 72.2),

and thereafter, Permittee shall continuously operate, and maintain the following during

boiler operations: an SNCR system for control ofNON, multiclone collectors and an ESPfor the control of PM, PM10and PM25,and good combustion practices for the control of

CO. Permittee shall also perform any necessary operations to minimize emissions so that

emissions are at or below the emission limits specified in this permit.

Permittee shall also to the extent practicable, maintain and operate equipment in a mannerconsistent with good air pollution control practice for minimizing emissions.

C. Steam Production and Emission Limitations

1. Except as noted below under Condition XD., on and after the date ofinitial startup,

Permittee shall not discharge or cause the discharge from Ui into the atmosphere inexcess ofthe following:

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Sierra Pacjflc Industries- Anderson (SAC 12-01)PSD Permit 2013
(

g

)

CO • 0.23 lb/MM i3tu (3-hour block average)

• EPA Method 1—4 and 10

• 0.02 lb/MMBtu (3-hour block average) PM, PM1I M2. • ).4 lbs/hr (hourly average)

2. CO emissions at all times from Ui, including startup and shutdown events as defmed

Conditions XD.3. andXD.4., shall not exceed 432 lbs/hr (houriy average).

3. Steam production from Ui shall not exceed 275,000 lbs/hr (24 hour block average).

4. Visible emissions from Ui, except for uncombined water vapor or during periods defined

• in Condition XD., shall not exceed 20% opacity in any six minute period, as verified by

the continuous opacity monitoring system (COMS).

5. Visible emissions from the Ui shall not exceed 40% opacity for more than three minutes

out of any one 60-minute period.

6. At all times, including equipment startup and shutdown, Permittee shall minimize the

cause or discharge ofthe following emissions:a. dust from unpaved roads or any other non-vegetation-covered area;

b. fugitive sawdust from fuel-handling devices and/or storage areas.

c. char and/or bottom ash which is processed by the char handling systems or removed

from Ui by other means.

d. accumulation ofsawdust or ash on outside surfaces including, but not limited to, the

main building, Ui, ESP, support pads, road areas. Surfaces shall be cleaned on aregular basis to prevent the build-up of ash and/or fugitive dust.

e. fuel dust or ash spilled due to an upset condition shall be cleaned up in a timely

manner. In no event shall spilled dust or ash be allowed to exist beyond 24 hours of

the upset.

D. Requirements during Startup and Shutdown

1. Only biomass fuels, as defmed in Condition X G. 1, and Public Utilities Commission

(PUC)-quality pipeline natural gas shall be fired during startup and shutdown

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Sierra Pacific Industries- Anderson (SAC 12-01)PSD Permit 2013
, 

p

g

g 

and concluding when the recorded superheater outlet temperature reaches 150°F and

remains so for at least one hour. During shutdown, the generator shall be separated from

the electrical grid.

5. For Ui, the duration ofstartup and shutdown periods and emissions ofNOR, CO, PM,

PM10 and PM2.5shall not exceed the following, as verified by the CEMS and fuel usage

data:

Table 5- Ui Startup and Shutdown Limits

NO, CO PM, PM1PM2 Duration

( hour average) ( hour average) (24 hour average)

Startup 70.2 lb/hr 108 lb/hr 8.93 lb/hr 24 hoursShutdown 70.2 lb/Iìi’ 108 lb/hr 8.93 lb/hr 24 hours

6. For Ui, the Permittee must operate the CEMS during startup and shutdown periods.

7. For Ui, the Permittee must record the time, date, and duration of each startup and

shutdown event.

8. For Ul, the Permittee must keep records that include calculations ofNON, CO, PM, PM10

PM25 and emissions in lb/hr and lb/MMBtu during each startup and shutdown event

based on the CEMS and fuel usage data.

E. Auxiliary Equipment Emissions Limitations

1. Permittee shall not discharge or cause the discharge from each unit into the atmosphere in

excess ofthe following:

Table 6- U2 and U3 Emission Limits

tJ2 113

NO • 0.78 lb/hr

CO

• 4.0 g/hp-hr (3-hour block average)

• 6.11 lb/hr

I’M! PM10 • 0.272 lbs/hr (hourly average) • 0.0216 lb/hr

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for Ui at which the SNCR system is recommended for operation to reduce NOemissions as defmed by the SNCR manufacturer. This temperature value shall beincluded in the operation and maintenance plan required by Condition III. C.

2. For Ui, SNCR systems for the control ofNO shall be in operation at all times that UI

exceeds the low SNCR activation temperature.

3. For Ui, the multiclones and ESP for the control of PM, PM10 and PM25 shall be in

operation at all times during the combustion process.

4. U3 shall not operate during startup ofUi, except when required for emergency

operations.

5. Wood waste collection and storage bin leaks shall be minimized at all times. All

identified wood waste collection and storage bin leaks, spills and upsets of any kind shall

be corrected or cleaned immediately, within 4 hours, as practicable, to correct the leak,

spill or upset.

6. Wood waste collection and storage bins shall be emptied on a schedule that ensures that

the cyclone-separator system does not become plugged.

7. Wood waste collection and storage bins, not including the fuel shed, shall remain

enclosed to mitigate the fugitive emissions from the unloading process.

8. All ash shall be transported in a wet condition in covered containers or stored in closed

containers at all times

9. Fugitive dust generated from access and on-site roads shall be minimized by application

of water, dust palliative, chip-sealing, or paving.

10. Fugitive dust from storage piles, processing area, and disturbed areas shall be minimized

by periodic cleanup and/or use ofspriniders, tarps, or dust a11iative agents.

11. During periods of high winds, Permittee shall take immediate action to correct fugitive

dust emissions from the chip processing area.

12. All necessary surfaces shall be cleaned or washed sufficiently to prevent wind-blown dust

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g 

g

and information noting the date when waste material was added.

16. The Permittee shall inspect all containers holding VOCs or waste, at least weekly, for

leaks and for deterioration caused by corrosion or other factors.

17. Containers holding ignitable or reactive waste must be located within the property

boundary at least 50 feet from the facility’s property line.

18. Incompatible wastes must not be placed in the same container. The treatment, storage,

and disposal of ignitable or reactive waste, and the commingling of wastes, or wastes and

materials, must be conducted so it does not:

a. Generate extreme heat, pressure, explosion, or violent reaction;

b. Produce uncontrolled toxic mists, fumes, dusts or gases in sufficient quantities to

threaten human health;

c. Produce flammable fumes or gases in sufficient quantities to pose a risk of fire or

explosions;

d. Damage the structural integrity ofthe device or facility containing the waste; ore. Through other means threaten human health or the environment.

G. Fuel Restrictions

1. The following biomass fuels shall constitute the only fuel allowed for use as fuel in Ui,

except during periods defined in Condition XD. and to counteract upset conditions:a. Untreated wood pallets, crates, dunnage, untreated manufacturing and construction

wood debris from urban areas;

b. All agricultural crops or residues;

c. Wood and wood wastes identified to follow all ofthe following practices;

i. Harvested pursuantto an approved timber management plan prepared inaccordance with the Z’berg-Nejedly Forest practice Act of 1973 or other locally or

nationally approved plan; andii. Harvested for the purpose offorest fire fuel reduction or forest standimprovement.

2. The heat input from pipeline natural gas shall not exceed 10% ofthe total heat input to

Ui on a 12-month rolling basis.

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a. Permittee shall install, calibrate, operate and quality assure a CEMS that measures

CO, NON, and CO2in ppmv.

b. Permittee shall conduct initial certification ofthe CEMS in accordance with

Condition XH.2.

c. Permittee shall operate and maintain a COMS capable ofmeasuring stack gas opacity

d. Permittee shall install a stack gas volumetric flowrate monitor and steam production

rate monitor.

2. The CEMS for Ul shall meet the applicable requirements of 40 CFR Part 60.13 and 40

CFR Part 60 Appendix B, and 40 CFR Part 60 Appendix F, Procedure 1.

3. Each CEMS shall complete a minimum of one cycle of operation (sampling, analyzing,

and data recording) for each successive 15-minute clock-hour period.

4. Data sampling, analyzing, and recording ofthe CEMS shall also be adequate to

demonstrate compliance with emission limits during startup and shutdown.

5. The initial certification ofthe CEMS may either be conducted separately or as part ofthe

initial performance test of U 1. The CEMS must undergo and pass initial performance

specification testing on or before the date ofthe initial performance test.

6. The CEMS shall be audited quarterly and tested annually to demonstrate that it meets the

specifications in Condition XH2. Permittee shall perform a full stack traverse during the

initial run of annual relative accuracy test auditing ofthe CEMS, with testing points

selected according to 40 CFR Part 60 Appendix A, Method 1.

7. Permittee shall submit a CEMS performance test protocol to the EPA no later than 30

days prior to the test date to allow review ofthe test plan and to arrange for an observer

to be present at the test. The performance test shall be conducted in accordance with the

submitted protocol and any changes required by EPA.

8. For Ui, opacity shall be monitored by a COMS that meets the applicable requirements of

40 CFR Part 60 Appendix B, Procedure 1.

9. The COMS shall have a span value of 100% and utilize a computer or other facility

which has the capability of interpreting sampling data and producing output to

demonstrate compliance with applicable standards. The span value for the continuous

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p

;

11. Permittee shall furnish the EPA with a written report ofthe results oftests within 60

days of completion.

12. Permittee shall continuously monitor the ESP for transformer/rectifier (T/R set) On/Off

status and Rapper On/Off status.

13. Permittee shall record hourly readings of ESP zone voltage (minimum 10 kilovolts,

maximum 60 kilovolts) and amps on the operator log.

14. For U3, permittee shall install and maintain an operational non-resettable elapsed time

meter to record the operating time ofthe emergency engine.

I. Performance Tests

1. Performance tests shall be conducted in accordance with the test methods set forth in 40

CFR Part 60.8 and 40 CFR Part 60- Appendix A, as modified below:

a. EPA Methods 1-4, 18 and 25A for VOC emissions. Methods 18 and 25A may both be

used simultaneously to quantifr the annual emissions ofthe organic compounds listed

in 40 CFR 51.100(s)(1) (using Method 18) and subtract this amount from the annual

total VOC emissions (as determined from Method 25A).

b. EPA Methods 1-4 and 6(c) for SO2emissions.c. EPA Methods 1-4 and 10 for CO emissions.d. EPA Methods 1-4 and 7 for NO emissions.e. EPA Methods 1-3 and 29 for Pb emissions.

f. EPA Methods 1-4 and 5 for PM emissions.g. EPA Methods 1-4, 5 and 202 with a two-hour test run period for each test for PM10

and PM25 emissions. In lieu ofMethod 5, the Permittee may use Other Test Method27. In lieu of Method 202, the Permittee may use Other Test Method 28.

h. The provisions of 40 CFR Part 60.8(f).

i. In lieu ofthe specified test methods, alternative methods may be used with prior

written approval from EPA.

2. ForUl,

a. Within 60 days after achieving normal operation, but not later than 120 days after the

modification, Permittee shall conduct initial performance tests (as described in 40

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beginning ten years after the initial performance test (within 30 days ofthe tenth

anniversary ofthe initial performance test date).

e. Permittee shall submit a performance test protocol to EPA no later than 30 days prior

to a performance test to allow review ofthe test plan and to arrange for an observer tobe present at the test. The performance test shall be conducted in accordance with the

submitted protocol, and any changes required by EPA.

3. For U2, the Permittee shall do the following:

a. Perform weekly tests ofthe blow-down water quality using an EPA-approved

method. The operator shall maintain a log that contains the date and result of each

blow-down water quality test, the water circulation rate at the time ofthe test, and theresulting mass emission rate. This log shall be maintained onsite for a minimum offive years and shall be provided to EPA and District personnel upon request.

b. Calculate PM, PM10 and PM2.5emission rate using an EPA-approved calculation

based on the total dissolved solids (TDS) and water circulation rate.

c. Conduct all required cooling tower water quality tests in accordance with an EPAapproved test and emissions calculation protocol. Thirty (30) days prior to the first

such test, the operator shall provide a written test and emissions calculation protocol

for EPA review and approval, with a copy to the District as specified in Condition

XII.

d. Establish a maintenance procedure that states how often and what procedures will be

used to ensure the integrity ofthe drift eliminators and to ensure compliance with

recirculation rates. This procedure is to be kept onsite and made available to EPA and

District personnel upon request. The permittee shall promptly report any deviationsfrom this procedure.

4. For U3, the Permittee shall conduct an initial performance test (as described in 40 CFR

Part 60.4244) for NOR, CO and emissions and at least every five years beginning ten

years after the initial performance test (within 30 days ofthe tenth anniversary ofthe

initial performance test date).

5. Upon written request from the Permittee, and adequate justification, EPA may waive a

specific annual test andlor allow for testing to be done at less than maximum operating

capacity.

J. Recordkeeping and Reporting

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s

a

eco

d t

e efficiency of Ui daily. 

e heat input, as determined from the

Ui efficiency and steam production rate, shall not exceed 468 MMBtu/hr on a monthlybasis.

3. For Ui, Permittee shall maintain the following records:

a. The total monthly hours of operation;

b. 3-hour averages of CO and NO emissions in units of lbs/MMBtu and lbs/hour dry

basis. All time periods when the boiler is not in operation shall be excluded from theaverages. The monthly average of CO and NO emissions expressed in lbs/hour shallalso be included;

c. 3-hour average calculations ofPM10 emissions in units ofibs/MIVIBtu and lbs/hour

dry basis using the most recent annual PM10 source test;

d. notification of all periods the continuous monitors were not functioning and the

reasons for the same;

e. steam production rate averaged over a daily (24-hour) period.

4. Permittee shall maintain CEMS and COMS records that include the following:

a. the occurrence and duration of any startup, shutdown, or malfunction, performance

testing, evaluations, calibrations, checks, adjustments maintenance, duration of any

periods during which a CEMS or COMS is inoperative, and corresponding emissionmeasurements.

b. date, place, and time of measurement or monitoring equipment maintenance activity;

c. operating conditions at the time ofmeasurement or monitoring equipment

maintenance activity;

d. date, place, name of company or entity that performed the measurement or

monitoring equipment maintenance activity and the methods used; and

e. results ofthe measurement or monitoring equipment maintenance.

5. Permittee shall maintain records nd submit a written report of all excess emissions and

opacity measurements to EPA and the District semi-annually, except when more frequent

reporting is specifically required by an applicable subpart; or the Administrator, on a

case-by-case basis, determines that more frequent reporting is necessar to accuratelyassess the compliance status ofthe source. The report is due on the 3O day following

the end of each semi-annual period and shall include the following:

a. Time intervals, data and magnitude ofthe excess emissions, the nature and cause (if

known), corrective actions taken and preventive measures adopted;

b. Applicable time and date of each period during which the CEMS or COMS was

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e. Any violation of limitations on operation, including but not limited to restrictions on

hours of operation.

6. A period ofmonitor down-time shall be any unit operating clock hour in which sufficient

data are not obtained by the CEMS to validate the hour for NOR, CO, or CO2.

7. Excess emissions shall be defmed as any period in which emissions exceed the emission

limits and standards set forth in Conditions XC.], XC.2, XC.3 andXD.5.

8. Excess emissions indicated by the CEMS, COMS, source testing, or compliance

monitoring shall be considered violations ofthe applicable emission limit or standard for

the purpose ofthis permit.

9. For Ui, daily records of fuel received other than natural gas shall be maintained. These

records shall include a detailed description of.the fuel supplier, fuel type and tonsreceived.

10. For U3, the permittee shall maintain records ofthe following: hours of operation, purpose

of operation, fuel usage on hourly basis and calculated PM/PM 10emissions based onmanufacturer emissions specifications and fuel usage data.

11. Unless otherwise specified herein, all records required by this PSD Permit shall be

retained for not less than five years following the date ofsuch measurements,maintenance, reports, and/or records.

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Code of Federal Regulations

Carbon MonoxideCarbon DioxideCombustion Turbine Generator

Conditional Test MethodContinuous Opacity Monitoring SystemCogeneration Unit

Shasta County Air Quality Management District

Dry Low NO

(dry) Standard Cubic Feet

Environmental Protection AgencyElectrostatic PrecipitatorGallons Per MinuteGrains

Higher Heating Value

HourPoundsMillion British Thermal Units

Megawatt

National Ambient Air Quality Standards

Nitrogen Dioxide

Oxides ofNitrogen

New Source Performance Standards

Total Particulate Matter

Particulate Matter with aerodynamic diameter less than 2.5 micrometersParticulate Matter with aerodynamic diameter less than 10 micrometersParts Per MillionParts Per Million by Volume, Dry basis

Parts Per Million by VolumePrevention of Significant DeteriorationRelative Accuracy Test Audit

Selective Catalytic ReductionSulfur Dioxide

Oxides of Sulfur

Total Dissolved SolidsTons Per Year

Year

CFRCOCO2

CTGCTMCOMSCU

DistrictDLN

(d)scf

EPAESP

gpm

gr

HRVhr

lbs

MMBtuMW

NAAQS

NO2NONSPSPMPM25PM10ppm

ppmvdppmvPSD

RATA

SCR502SOX

TDS

tpy

yr

Sierra Pacflc Industries- Anderson (SAC 12-01)

PSDPer,nit2Ol3

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San Francisco, CA 94105-3901

Email: R9.AEOepa.govFax: (415) 947-3579

With a copy to:

B. Air Pollution Control Officer

Shasta County Air Quality Management District

1855 Placer Street, Suite 101

Redding, CA 96001 -Fax (661)723-3450

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