### PREVENTION OF SIGNIFICANT DETERIORATION PERMIT ISSUED PURSUANT TO THE REQUIREMENTS AT 40 CFR § 52.21
U.S. ENVIRONMENTAL PROTECTION AGENCY, REGION IX PSD PERMIT NUMBER: SAC 08-01 PERMITTEE: Covanta Energy Corporation 40 Lane Road Fairfield, NJ 07004 FACILITY NAME: Burney Mountain Power FACILITY LOCATION: 37800 Energy Drive Burney, California 96013
Pursuantto the provisions ofthe CleanAir Act (CAA), Subchapter I, Part C (42 U.S.C. Section 7470, 

### et. seq.), and the Code ofFederal Regulations (CFR) Title 40, Section 52.21, the United States Environmental Protection Agency Region 9 (EPA) is issuing a 

### Prevention of Significant Deterioration (PSD) air quality permitto Covanta Energy Corporation (Covanta). This Permit applies to the modification and operation ofa 10.2 megawatt (MW) biomass powerplantknown as BurneyMountain Power (BMP) in Burney, California.
Covantais authorized to construct and operate the BMP powerplant as described herein, in accordance withthe permit application (and plans submitted withthe permit application), the federal PSD regulations at 40 CFR § 52.21, and otherterms and conditions set forth in this PSD Permit. Failure to comply with any condition orterm set forth in this PSD Permit may be subject to enforcement action pursuant to Section 113 ofthe Clean Air Act. This PSD Permit does not relieve Covanta from the obligation to comply with applicable federal, state, and Shasta County Air Quality Management District air pollution control rules andregulations. This PSD Permitbecomes effective onthe date ofissuance pursuantto 40 CFR § 124.15(b)(3).

Director, AirDivision

Burney Mountain Power (SAC 08-01) Final PSD Permit/October 201 0 DatePSD PERMIT NUMBER: SAC 08-01 BURNEY MOUNTAIN POWER U.S. ENVIRONMENTAL PROTECTION AGENCY, REGION IX

PROJECT DESCRIPTION Burney Mountain Power (BMP) is a 10.2 MWbiomass-firedpowerplantthat employs a Zurn wood-fired Boiler. The applicant is including additional types ofbiomass to its allowable fuel feed and installing a 75 horsepower hammer hog onthe fuel feed inlet. The additional fuels allowed to be utilized include: peach pits, walnut shells, sander dust, urban wood fuel, waste wood roofing shakes with tarpaper component, and waste activated carbon. Previous editions ofthe PSD Permit were issued by Shasta County Air Quality Management District (the District). OnMarch 3, 2003 USEPArevoked and rescinded the District's authority to issue and modify federal PSD permits for new and modified major sources ofattainmentpollutants. Therefore, EPA is modifying the PSD Permit issued by the Districtto incorporate the proposed modifications.
EQUIPMENT LIST Emission Description Unit Id. EU-1 One (1) 190MMBTU/hrZurnwood-fired boiler equipped withtwo (2) 22 MMBTU/hrpipeline natural gas-fired burners and a flue gas recirculation system EU-2 50 T/hr truck dump (fugitive emissions) EU-3 12 T/hr hammerhog (fugitive emissions) EU-4 50 T/hr fuel storage stackout conveyer (fugitive emissions) EU-5 50 T/hr fuel storage hammer hog (fugitive emissions) EU-6 50 T/hr fuel storage reclaimer/conveyor (fugitive emissions) EU-7 7600 GPM evaporative cooling tower (fugitive emissions)

PERMIT CONDITIONS I. Permit Expiration As provided in 40 CFR 52.21(r), this PSD Permit shall become invalid ifconstruction: 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.

Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 

### 1

### II. Permit Notification Requirements Permittee shall notify EPA Region 9 in writing or by electronic mail ofthe: A. date construction is commenced, postmarked within 30 days ofsuch date. B. actual date that permittee will commence operation as modified source, postmarked within 15 days ofsuch date. C. date upon which initial performance tests will commence, in accordance with the provisions ofCondition X.F.1., postmarked not less than 30 days priorto such date. Notification may be provided withthe submittal ofthe performance test protocol required pursuant to ConditionX.F.2. D. date upon which initial performance evaluation ofthe 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 pursuantto Condition X.C.6.


### III. Facility Operation At all times, including periods ofstartup, shutdown and malfunction, Permittee shall, to the extentpracticable, maintain and operate the facility including associated air pollution control equipment in a manner consistent with good airpollution control practice for minimizing emissions. Determination ofwhether acceptable operating and maintenance procedures are being used will be based oninformation available to the EPA which may include, but is not limited to, monitoring results, opacity observations, review of operating maintenance procedures and inspection ofthe source.


### IV. Malfunction Reporting A. Permittee shall notifyEPAby facsimile or electronic mail withintwo (2) working days following the discovery ofany failure ofair pollution control equipment, process equipment, or ofa process to operate in a normal manner, which results in an increase in emissions above the allowable emission limits stated in Section X.D. ofthis permit. B. In addition, Permittee shall notify EPA in writing or electronic mail within fifteen (15) days ofany such failure described under Condition IV.A. The notification shall include a description ofthe malfunctioning equipment or abnormal operation, the date ofthe initial malfunction, the period oftime overwhich emissions were increased due to the failure, the cause ofthe failure, the estimated resultant emissions in excess of those allowed in SectionX.D., and the methods utilized to mitigate emissions and restore normal operations. C. Compliance withthis malfunction notificationprovision shall not excuse or otherwise constitute a defense to any violation ofthis permit or any law orregulation such malfunction may cause.

Burney Mountain Power (SAC 08-01) Final PSD PermiUOctober 2010 2

### V. Right ofEntry The EPA Regional Administrator, and/or an authorized representative, uponthe presentation ofcredentials, shall bepermitted: A. to enter the premises where the source is located or where any records are required to be keptunderthe terms and conditions ofthis PSD Permit; and B. during normal business hours, to have access to and to copy any records required to be kept underthe terms and conditions ofthis PSD Permit; and C. to inspect any equipment, operation, ormethod subjectto requirements in this PSD Permit; and D. to sample materials and emissions from the source(s).


### VI. Transfer ofOwnership In the event ofany changes in control or ownership ofthe facilities to be constructed, this PSD Permit shall be binding on all subsequent owners and operators. Permittee shall notify the succeeding owner and operator ofthe existence ofthis PSD Permit and its conditions by letter, a copy ofwhich shall be forwarded to EPA Region 9.


### VII. Severability The provisions ofthis PSD Permit are severable, and, ifany provision ofthe PSD Permit is held invalid, the remainder ofthis PSD Permit shall not be affected.


### VIII. Other Applicable Regulations Permittee shall construct and operate this project in compliance withthis PSD permit and all other applicable federal, state, and local air qualityregulations. This PSD permit does not release the Permittee from any liability for compliance with other applicable federal, state and local environmental laws and regulations, including the Clean Air Act.


### IX. RESERVED
X. Special Conditions A. Reserved

B. Air Pollution Control Equipment, Operation and WorkPractices 1. The following air pollution control equipment shall be used at all times that biomass is used inthe combustionprocess: Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 3a. char reinjection b. multiclone collector
c. electrostatic precipitator (ESP) d. combustion controls 2. Good combustion practices, including but not limited to control ofunderfire air, control ofoverfire air, and control ofcombustion excess air shall be exercised at all times. 3. Sander dust and waste activated carbon shall be mixed with biomass wood fuel upon arrival in the fuel yard or stored in closed containers until use. 4. All ash shall be transported in a wet condition in covered containers. It shall be the responsibility ofthe Permittee to ensure that any and all contract or company carriers adhere to this condition. 5. Fugitive emissions, inCluding but not limitedto any ofthe following, shall be minimized at all times:
a. Dust from unpaved roads or any other non-vegetation covered area. b. Fugitive sawdust from fuel-pile areas orfuel-handling devices.
c. Char and/orbottom ash which is processed by the char handling system or is removed from the boiler by othermeans. d. 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 ofthe upset. 6. Visible emissions shall be inspected daily. Ifvisible emissions are observed, corrective action shall be taken to minimize visible emissions. Ifvisible emissions cannot be corrected within 24 hours, then a visible emissions test using EPA Method 22 shall be performed within 48 hours ofwhenthe visible emissions were first observed. 

### C. Continuous Monitoring Systems 1. Permittee shall operate, maintain, certifY, and quality-assure a continuous emission monitoring system (CEMS) which measures stack gas NOx, CO and 

### 02 concentrations inppmv, a continuous emission rate monitoring systems (CERMS) which measures stack gas NOx in lbs/hr and a continuous opacity monitoring system (COMS) which measures stack gas opacity onEU-1. 2. The Permittee shall operate and maintain devices as necessary to monitorthe following parameters inthe combustionprocess:
a. stack gas flow rate b. combustiontemperature (at the superheatertube area)
Burney Mountain Power (SAC 08-01) Final PSD Permit/October 201 0 4c. temperature at inlet/outlet ofESP d. steamproductionrate 3. NOx and 

### 0 2CEMS shall meetthe applicable requirements of40 CFRPart 60 Appendix B, Performance Specifications 2 and 3 upon initial installation, and 40 CFRPart 60 Appendix F, Procedure 1thereafter. 4. The CO CEMS shall meetthe applicable requirements of40 CFRPart 60 Appendix B, Performance Specification4Aupon initial installation, and 40 CFR Part 60 Appendix F, Procedure 1thereafter. 5. The performance evaluation ofthe CEMS and CERMS to monitorthe stack gas flow may either be conducted separately or as part ofthe newfuel mixture source test. 6. Permittee shall submit a CEMS and CERMS performance test protocol to the EPAno laterthan 30 days priorto the test date to allowreview ofthe testplan and to arrange for an observerto bepresent atthe test. The performance test shall be conducted in accordance withthe submittedprotocol, and any changes required by EPA. 7. The CEMS and CERMS shall be tested annually in accordance withthe requirements of40 CFR 60 Appendices B and F. 8. The CEMS shall complete a minimum ofone cycle ofoperations (sampling, analyzing and datarecording) for each successive IS-minuteperiod. 9. Permittee shall furnish the EPA a written report ofthe results ofCEMS and CERMS performance tests within 60 days ofcompletion. D. Production, Operation and Emission Limits 1. The following production and operation limits shall apply at all times:
a. Steamproductionrate shall not exceed 120,000 lbslhr. b. Operation ofthe boiler shall not exceed 8,400 hours on a 12-monthrolling basis. 2. The following annual facility emission limits shall apply on a 12-monthrolling basis:
a. PM emissions shall not exceed 33 tpy. b. PM10 emissions shall not exceed 23 tpy.
c. PM2.s emissions shall not exceed 18 tpy. d. VOC emissions shall not exceed 109 tpy.
e. so2 emissions shall not exceed 22 tpy. f. NOx emissions shall not exceed 139 tpy. Burney Mountain Power (SAC 08-01) Final PSD Permit/October 201 0 

### 5g. CO emissions shall not exceed 790 tpy. 3. The following emission limits shall apply to EU-1 at all times, except as provided by the provisions in SectionX.E.
a. PM emissions shall not exceed 0.05 gr/dscfat 12% C02. b. S02 emissions shall not exceed 15 ppm on an hourly average basis at 12% C02.
c. VOC emissions shall not exceed 26 lbs/hr, based on a 3-hour averaging period. d. CO emission concentrations shall not exceed the following:
1. 1200 ppm (dry basis, corrected to 12% C02 ) whenburningbiomass only, based on a rolling 24-hour average
11. 400 ppm (drybasis, corrected to 12% C02 ) whenburningpipeline natural gas only, based on a rolling 3-hour average
111. When firing a combination ofgaseous and solid fuel (dry basis, corrected to 12% C02), Z, as determined bythe following equationbased on a rolling 24-hour average: (400

## *X) 

### +(1200

## *Y) =

# z X+Y where; Z = ppm limit offiring combination X = annual heat input from gaseous fuel 

### Y = annual heat input from non- gaseous fuel 4. Except during periods ofstartup and shutdown as defined in Conditions X.E.2 and X.E.3., 

### NOx emission concentrations from EU-1 shall not exceed the following at all times, based on a rolling 3-hour average ofCEMS data:
a. When burning biomass: either 115 ppm (dry basis at 12% C02) or 0.15 lbs/MMBTU heat input, b. Whenburning pipeline natural gas only: either 70 ppm (dry basis at 3%.02) or 0.084 lbs/MMBTU ofheat input
c. Whenfiring a combination ofgaseous and solid fuel (dry basis, corrected to 12% C02 ), Z 1 and Z2, as determined by the following equation: (70

## *X) 

### +(115

## *Y) = 

# z X+Y 1 (0.084 *X)+(0.15

## *Y)

_ Z X+Y

- 2 where; 

## zl =ppm limit offiring combination Z2= lbs/MMBTU limit offiring combination Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 

### 6X = annual heat input from gaseous fuel Y = annual heat input from non-gaseous fuel 5. NOx emissions shall not exceed 33 lbs/hr, based on a 24-hour daily average of CERMS data. All periods ofinoperation shall be excluded from the calculated average.


### E. Requirements during Malfunction, Startup and Shutdown Periods 1. During start-up and shutdown ofthe boiler, the PM concentration shall not exceed 0.1 gr/dscf. 2. Startup is defined as the period beginning with EU-1 ignition and lasting until the equipment has reached a continuous operating level and the emission limits specified in ConditionX.D.3. 3. Shutdown is defined as the period beginning with the lowering ofequipment from normal operating load and the start ofnatural gas burners at a minimum firing rate, and lasting until the concentration of02 inside EU-1 is at or above 18%, orEU-1 is offline. 4. Startup and shutdownperiods shall not exceed three hours in duration.


### F. Performance Tests 1. Performance tests shall be conducted in accordance with the test methods set forth in 40 CFR 60.8 and 40 CFR 60- Appendix A, as modified below:
a. EPA Methods 1-4, 18 and 25A for VOC emissions. Methods 18 and 25A may bothbe used simultaneouslyto quantifY the annual emissions ofthe organic compounds listed in 40 CFR 51.100(s)(l) (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 S02 emissions.
c. EPA Methods 1-3 and 29 for Pb emissions. d. EPA Methods 1-4 and 5 for PM emissions.
e. EPAMethods 1-4, 5 and 202 with a two-hour test runperiod for each test for PM 10and PM2

_ 5 emissions. In lieu ofMethod 5, the Permittee may use Other Test Method 27. In lieu ofMethod 202, the Permittee mayuse Other Test Method 28. f. The provisions of40 CFR Part 60.8(±). 2. Permittee shall submit a performance test protocol to EPA no later than 30 days priorto the testto allowreview ofthetest plan and to arrange for an observerto be present at the test. The performance test shall be conducted in accordance with the submitted protocol, and any changes required by EPA. Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 73. In lieu ofthe specified test methods, alternative methods may be used with prior written approval from EPA. 4. Within 60 days after achieving the facility's maximum operating productionrate, but not laterthan 120 days after the modification, permittee shall conduct initial performance tests (as described in 40 CFR 60.8) for NOx CO, PM, PM 10, PM2.5, and VOC emissions.
a. After achieving the maximum production rate, initial performance tests for Pb and SOz shall be completed within 120 after receiving fuels X.I.l.i, X.I.l.j and X.I.l.k. b. Annual performance tests shall be required for PM 10. 5. Annual source tests ofthehighheating value (HHV) in Btu/lb shall be required of all mill waste received at the facility. 6. Forperformance testpurposes, sampling ports, platforms, and access shall be provided onthe emission unit exhaust system in accordance withthe requirements of40 CFR 60.8(e). 7. Uponwritten request from the Permittee, and adequatejustification, EPA may waive a specific annual test and/or allow for testing to be done at less than maximum operating capacity.


### G. Recordkeeping and Reporting 1. Permittee shall maintain daily electrical generation data on site. 2. Permittee shall maintain records ofthe hours ofoperation for E/U's 1, 2 and 3, on a 12-monthrolling basis updated by the 15th day ofthe following month. 3. Permittee shall maintain CEMS and CERMS records that contain the following: the occurrence and duration ofany startup, shutdown ormalfunction, performance testing, evaluations, calibrations, checks, adjustments, maintenance, duration of anyperiods during which a continuous monitoring system or monitoring device is inoperative (monitor downtime), except for zero and span checks, and the nature ofsystem repairs or adjustments, and emission measurements. 4. A period ofmonitor downtime shall be any EU-1 operating hour in which sufficient data are not obtained to validate the hour for NOx, CO or Oz. 5. Excess emissions as measured by the CEMS and CERMS, shall be defined as follows:
a. ForNOx, 1. any operating hour, excluding periods ofstartup and shutdown as defined in Conditions X.E.2.,X.E.3. and X.E.4., in whichthe rolling 3-hour average NOx concentration exceeds the maximum emission limit set forth in Condition X.D.4.a, or
Burney Mountain Power (SAC 08-01) Final PSD PermiUOctober 201 0 8u. any day inwhichthe average NOx mass exceeds the maximum emission limit set forth in Condition X.D.5. b. For CO, any operating hour in whichthe rolling 24-hour average CO concentration exceeds the maximum emission limits set forth in Condition X.D.3.f.i. 6. Permittee shall maintain records and a summary report ofall excess emissions on site. The records and summaryreport shall contain information according to 40 CFR 60.7(c) and (d), including:
a. Time intervals, data, and magnitude ofthe excess emissions, the nature and cause (ifknown), corrective actions taken and preventive measures adopted; b. Applicable time and date ofeachperiod during whichthe CEMS or CERMS was inoperative (monitor down time); and
c. A negative declaration when no excess emissions occurred or whenthe CEMS orCERMS has not been inoperative, repaired, or adjusted. 7. Excess emissions indicated bythe CEMS shall be considered violations ofthe applicable emission limit for the purpose ofthis permit. 8. Permittee shall submit excess emissions reports to EPA semiannually. The report is due onthe 30th dayfollowing the end ofthe calendar quarter. 9. Permittee shall submitto EPA a writtenreport ofthe results ofperformance tests within 60 days ofcompletion. 10. Records offuel dust or ash spilled due to an upset condition shall be kept on site. Spills that are allowed to existbeyond 24 hours ofthe upset shall be reported to the District. 11. Records ofvisible emissions testsusing EPAMethod 22 shall be kept on site. Facility staffshall report the results ofthe testto the District. 12. Records ofthe total heat input and input specifically from pipeline natural gas to the boiler shall be derived from the power output ofthe biomass boilerrecorded on anhourly basis. 13. The Permittee shall maintain records ofall fuel deliveries, excluding pipeline natural gas, which include the fuel type, the date received, fuel source and weight in bone-drytons (BDT). 14. The Permittee shall maintain records ofeachtype and total fuels received, other than natural gas, on a monthly basis. 15. The Permittee shall maintainrecords ofall source tests for mill waste that include the HHV ofthe fuel as received and dry. 16. The Permittee shall maintainrecords ofthe monthlypipeline natural gas used for the boilerthat include the HHV-and volume received. 17. The Permittee shall maintain records ofcontracts from each vendor delivering biomass fuel procured from private and/or public lands which verify that the fuel Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 

### 9was harvested in accordance with the State Forest Practice Act or a Management Plan consistent with the National Environmental Policy Act. 18. The Permittee shall maintain records which demonstrate that wood, lumber, brush orvegetation from land clearings conducted as part ofa land development project have beenreviewed and approved by Shasta County, the City ofAnderson, the City ofRedding, orthe City ofShastaLake. 19. The Permittee shall maintain records which demonstrate that deliveries ofwaste activated carbonwere derived from municipal drinking water filtration systems. Material Safety Data Sheets and Materials CharacterizationFormspertaining to waste activated carbon fuel shall be kept on site. 20. All records required bythis PSD Permit shall be retained on site for five years following the date ofsuch measurements, maintenance, and reports.
H. Reserved

I. Fuel Use 1. Fuels received atthis facility shall be limited to the following on a 12-month rolling basis:
a. Mill waste b. Biomass fuel procured from private and/orpublic lands
c. Wood, lumber, brush orvegetation from Pacific Gas and Electric and public road right-of-ways d. Wood, lumber, brush orvegetation from land clearings conducted as part ofa land development project
e. Olivepits, up to 5% by weight oftotal annual fuel received 

### f. Almond shells, up to 10% by weight oftotal annual fuel received g. Peachpits, upto 10% by weight oftotal annual fuel received h. Walnut shells, up to 10% by weight oftotal annual fuel received
1. Sander dust, up to 10% byweight oftotal annual fuel received J. Urban wood fuel, up to 10% byweight oftotal annual fuel received, not to exceed 9,000 bone-dry tons peryear (BDT/yr) k. Waste woodroofing shakes withtarpaper component, up to 10% by weight of

- total annual fuel received, not to exceed 9,000 BDT/yr 

### 1. Waste activated carbon, derived from municipal drinking water filtration, at up to 1% ofweight oftotal annual fuel received, notto exceed 900 BDT/yr. The waste activated carbonreceived must not be classified as a hazardous waste based on federal, state orlocal regulations. Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 102. "Urban wood fuel" shall be limited to the following materials:
a. Yard, and garden clippings, including: grass, leaves, tree and branch pruning b. Vegetation from residential and commercial operations
c. Chipped material derived from construction and demolition materials including woodpallets, crates, and boxes. 3. Foreign material such as tar paper, nails, oil, plastics, styrofoam, rubber, paint, or other non-wood substances shall not exceed 3% by weight ofthe urban wood fuel mix. Upon the request oftheEPA Regional Administrator, Air Pollution Control Officer ofthe District and/or an authorizedrepresentative, the Permittee shall weigh all urban wood fuel to verify compliance. 4. Mill waste shall be defined as waste wood from wood manufacturing operations. 5. At least 45% ofthe heat input from fuels utilizedfor this facility, calculated on a 12-monthrolling basis, shall be non-mill waste derived. 6. The Permittee shall notuse a new fuel type ofany kind or change the maximum percent ofa fuel type to be received withoutprior approval from EPA in writing. 7. The pipeline natural gas auxiliaryburners shall only be used during startup and shutdown as defined in Section X.E., and to augment combustion stabilization. 8. The heat input from pipeline natural gas shall not exceed 25% ofthe total heat input to the boiler on a 12-monthrolling basis. 9. Pipeline natural gas, per 40 CFR 72.2, shall be defined as a naturally occurring fluid mixture ofhydrocarbons (e.g., methane, ethane, or propane) which is provided by a supplierthrough a pipeline. Pipeline natural gas contains 0.5 grains or less oftotal sulfurper 100 standard cubic feet. Additionally, pipeline natural gas must eitherbe composed ofat least 70 percent methane by volume orhave a gross calorific value between 950 and 1100 Btu per standard cubic foot. 10. The fuel dryer shall be used whenthe average fuel moisture is equal to or greater than 50%. However, inthe event ofa fuel dryer breakdown, the plant may continue operationprovided that the facility complies with all emission limit conditions inthis permit and a breakdown report is submitted to EPA as required in Condition IV.B. ofthis permit.


### XI. Agency Notifications A. Unless otherwise directed bythe EPA or this permit, the Permittee shall submit a copy ofall test plans, reports, certifications, notifications, and other information pertaining to compliance withthis permitto: Director, Air Division (Attn: Air-5) U.S. Environmental Protection Agency, Region 9 75 Hawthorne Street Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 

### 11SanFrancisco, CA 94105-3901 Email: R9.AEO@epa.gov Fax: (415) 947-3579
B. The Permittee shall submitpermit applications, permit amendments, and other applicable permit information, which includes but not limitedto installation ofcontrol equipment, replacement ofan emissions unit, and changes that contravene permit terms, to: Director, Air Division (Attn: AIR-3) U.S. Environmental Protection Agency, Region 9 75 Hawthorne Street San Francisco, CA 94105-3901
C. Copies ofall correspondence required by this PSD Permit shall be forwarded to:
Air Pollution Control Officer Shasta County APCD 1855 Placer St. Suite 101 Redding, CA 96001

Burney Mountain Power (SAC 08-01) Final PSD Permit/October 2010 12